W&T OFFSHORE INC - Quarter Report: 2023 June (Form 10-Q)

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

Form 10-Q

☑	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended June 30, 2023

☐TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from _______________ to ________________

Commission File Number 1-32414

W&T OFFSHORE, INC.

(Exact name of registrant as specified in its charter)


Texas		72-1121985
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

5718 Westheimer Road, Suite 700, Houston, Texas		77057-5745
(Address of principal executive offices)		(Zip Code)

Registrant’s telephone number, including area code: (713) 626-8525

Securities registered pursuant to section 12(b) of the Act:


Title of each class	Trading Symbol(s)	Name of each exchange on which registered
Common Stock, par value $0.00001	WTI	New York Stock Exchange

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports) and (2) has been subject to such filing requirements for the past 90 days. Yes ☑ No ☐

Indicate by check mark whether the registrant has submitted electronically every interactive data file required to be submitted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes ☑ No ☐

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, smaller reporting company or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company” and “emerging growth company” in Rule 12b-2 of the Exchange Act.


Large accelerated filer ☐	Accelerated filer	☑
Non-accelerated filer ☐	Smaller reporting company	☐
	Emerging growth company	☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐

Indicate by check mark whether the registrant is a shell company. Yes ☐ No ☑

As of July 31, 2023 there were 146,480,637 shares outstanding of the registrant’s common stock, par value $0.00001.

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W&T OFFSHORE, INC. AND SUBSIDIARIES

TABLE OF CONTENTS

		Page
PART I – FINANCIAL INFORMATION		1

Item 1.	Financial Statements	1
	Condensed Consolidated Balance Sheets as of June 30, 2023 and December 31, 2022	1
	Condensed Consolidated Statements of Operations for the Six Months Ended June 30, 2023 and 2022	2
	Condensed Consolidated Statements of Changes in Shareholders’ Equity (Deficit) for the Six Months Ended June 30, 2023 and 2022	3
	Condensed Consolidated Statements of Cash Flows for the Six Months Ended June 30, 2023 and 2022	4
	Notes to Condensed Consolidated Financial Statements	5
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	22
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	40
Item 4.	Controls and Procedures	40

PART II – OTHER INFORMATION		41
Item 1.	Legal Proceedings	41
Item 1A.	Risk Factors	41
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	41
Item 3.	Defaults Upon Senior Securities	41
Item 4.	Mine Safety Disclosures	41
Item 5.	Other Information	41
Item 6.	Exhibits	41

SIGNATURE		43

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PART I – FINANCIAL INFORMATION

Item 1. Financial Statements

W&T OFFSHORE, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(In thousands)

(Unaudited)


	June 30,		December 31,
	2023		2022
Assets
Current assets:
Cash and cash equivalents	$	171,627	$	461,357
Restricted cash		4,417		4,417
Receivables:
Oil and natural gas sales		41,342		66,146
Joint interest, net		13,875		14,000
Income taxes		1,941		—
Total receivables		57,158		80,146
Prepaid expenses and other assets (Note 1)		21,365		24,343
Total current assets		254,567		570,263

Oil and natural gas properties and other, net (Note 1)		737,740		735,215

Restricted deposits for asset retirement obligations		22,092		21,483
Deferred income taxes		45,700		57,280
Other assets (Note 1)		42,118		47,549
Total assets	$	1,102,217	$	1,431,790
Liabilities and Shareholders’ Equity
Current liabilities:
Accounts payable	$	67,293	$	65,158
Undistributed oil and natural gas proceeds		31,178		41,934
Advances from joint interest partners		3,110		3,181
Asset retirement obligations (Note 7)		37,763		25,359
Accrued liabilities (Note 1)		39,323		74,041
Current portion of long-term debt, net		30,550		582,249
Income tax payable		10		412
Total current liabilities		209,227		792,334
Long-term debt (Note 2)
Principal		382,697		114,158
Unamortized debt issuance costs		(9,676)		(2,970)
Long-term debt, net (Note 2)		373,021		111,188

Asset retirement obligations, less current portion (Note 7)		443,069		441,071
Other liabilities (Note 1)		35,041		59,134
Deferred income taxes		72		72
Commitments and contingencies (Note 11)		16,996		20,357
Shareholders’ equity:
Preferred stock, $0.00001 par value; 20,000 shares authorized; none issued at June 30, 2023 and December 31, 2022		—		—
Common stock, $0.00001 par value; 200,000 shares authorized; 149,350 issued and 146,481 outstanding at June 30, 2023; 149,002 issued and 146,133 outstanding at December 31, 2022		1		1
Additional paid-in capital		579,849		576,588
Retained deficit		(530,892)		(544,788)
Treasury stock, at cost; 2,869 shares at June 30, 2023 and December 31, 2022		(24,167)		(24,167)
Total shareholders’ equity		24,791		7,634
Total liabilities and shareholders’ equity	$	1,102,217	$	1,431,790

See Notes to Condensed Consolidated Financial Statements.

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W&T OFFSHORE, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(In thousands, except per share data)

(Unaudited)


	Three Months Ended June 30,				Six Months Ended June 30,
	2023		2022		2023		2022
Revenues:
Oil	$	89,982	$	159,264	$	186,982	$	281,966
NGLs		10,385		16,735		18,180		30,555
Natural gas		23,438		92,413		48,242		143,779
Other		2,376		5,396		4,502		8,512
Total revenues		126,181		273,808		257,906		464,812
Operating expenses:
Lease operating expenses		66,021		52,976		131,207		96,387
Gathering, transportation and production taxes		6,802		9,181		12,938		14,448
Depreciation, depletion, and amortization		28,177		27,679		50,801		52,354
Asset retirement obligations accretion		7,717		6,681		15,227		12,917
General and administrative expenses		17,393		14,967		37,312		28,743
Total operating expenses		126,110		111,484		247,485		204,849
Operating income		71		162,324		10,421		259,963

Interest expense, net		10,323		18,183		25,036		38,066
Derivative (gain) loss, net		(829)		(8,854)		(40,069)		71,143
Other (income) expense, net		(311)		(1,534)		(78)		(629)
Income (loss) before income taxes		(9,112)		154,529		25,532		151,383
Income tax expense		2,997		31,093		11,636		30,404
Net (loss) income	$	(12,109)	$	123,436	$	13,896	$	120,979

Net income per common share:
Basic	$	(0.08)	$	0.86	$	0.09	$	0.85
Diluted	$	(0.08)	$	0.85	$	0.09	$	0.84
Weighted average common shares outstanding:
Basic		146,452		143,020		146,435		142,981
Diluted		146,452		144,525		149,045		144,094

See Notes to Condensed Consolidated Financial Statements.

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W&T OFFSHORE, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN SHAREHOLDERS’ EQUITY (DEFICIT)

(In thousands)

(Unaudited)


	Common Stock			Additional							Total
	Outstanding			Paid-In		Retained		Treasury Stock			Shareholders’
	Shares	Value		Capital		Deficit		Shares	Value		Equity
Balances at March 31, 2023	146,461	$	1	$	577,787	$	(518,783)	2,869	$	(24,167)	$	34,838
Share-based compensation	—		—		2,087		—	—		—		2,087
Stock issued	20		—		—		—	—		—		—
RSUs surrendered for payroll taxes	—		—		(25)		—	—		—		(25)
Net loss	—		—		—		(12,109)	—		—		(12,109)
Balances at June 30, 2023	146,481	$	1	$	579,849	$	(530,892)	2,869	$	(24,167)	$	24,791


	Common Stock			Additional							Total
	Outstanding			Paid-In		Retained		Treasury Stock			Shareholders’
	Shares	Value		Capital		Deficit		Shares	Value		Deficit
Balances at March 31, 2022	143,012	$	1	$	553,175	$	(778,394)	2,869	$	(24,167)	$	(249,385)
Share-based compensation	—		—		2,014		—	—		—		2,014
Stock issued	143		—		—		—	—		—		—
RSUs surrendered for payroll taxes	—		—		(434)		—	—		—		(434)
Net income	—		—		—		123,436	—		—		123,436
Balances at June 30, 2022	143,155	$	1	$	554,755	$	(654,958)	2,869	$	(24,167)	$	(124,369)


	Common Stock			Additional							Total
	Outstanding			Paid-In		Retained		Treasury Stock			Shareholders’
	Shares	Value		Capital		Deficit		Shares	Value		Equity
Balances at December 31, 2022	146,133	$	1	$	576,588	$	(544,788)	2,869	$	(24,167)	$	7,634
Share-based compensation	—		—		4,009		—	—		—		4,009
Stock issued	348		—		—		—	—		—		—
RSUs surrendered for payroll taxes	—		—		(748)		—	—		—		(748)
Net income	—		—		—		13,896	—		—		13,896
Balances at June 30, 2023	146,481	$	1	$	579,849	$	(530,892)	2,869	$	(24,167)	$	24,791


	Common Stock			Additional							Total
	Outstanding			Paid-In		Retained		Treasury Stock			Shareholders’
	Shares	Value		Capital		Deficit		Shares	Value		Deficit
Balances at December 31, 2021	142,863	$	1	$	552,923	$	(775,937)	2,869	$	(24,167)	$	(247,180)
Share-based compensation	—		—		2,534		—	—		—		2,534
Stock issued	292		—		—		—	—		—		—
RSUs surrendered for payroll taxes	—		—		(702)		—	—		—		(702)
Net income	—		—		—		120,979	—		—		120,979
Balances at June 30, 2022	143,155	$	1	$	554,755	$	(654,958)	2,869	$	(24,167)	$	(124,369)

See Notes to Condensed Consolidated Financial Statements.

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W&T OFFSHORE, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(In thousands)

(Unaudited)


	Six Months Ended June 30,
	2023		2022
Operating activities:
Net income	$	13,896	$	120,979
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, depletion, amortization and accretion		66,028		65,271
Amortization and write off of debt issuance costs		4,363		4,365
Share-based compensation		4,009		2,534
Derivative (gain) loss		(40,069)		71,143
Derivative cash (payments) receipts, net		(4,427)		70,227
Derivative cash premium payments		—		(46,111)
Deferred income taxes		11,580		27,031
Changes in operating assets and liabilities:
Oil and natural gas receivables		24,804		(44,236)
Joint interest receivables		125		(3,625)
Prepaid expenses and other assets		26,992		(30,092)
Income tax		(2,345)		3,223
Asset retirement obligation settlements		(11,841)		(39,775)
Cash advances from JV partners		(71)		(9,813)
Accounts payable, accrued liabilities and other		(43,412)		46,638
Net cash provided by operating activities		49,632		237,759
Investing activities:
Investment in oil and natural gas properties and equipment		(22,999)		(25,489)
Changes in operating assets and liabilities associated with investing activities		(2,338)		(5,786)
Acquisition of property interests		—		(47,625)
Purchase of corporate aircraft (Note 12)		(8,983)		—
Purchases of furniture, fixtures and other		(218)		—
Net cash used in investing activities		(34,538)		(78,900)
Financing activities:
Repayment of Note Payable		(183)		—
Issuance of 11.75% Senior Second Lien Notes		275,000		—
Repayments on 9.75% Second Senior Lien Notes		(552,460)		—
Repayments on Term Loan		(19,181)		(24,941)
Debt issuance costs		(7,252)		(1,290)
Other		(748)		(703)
Net cash used in financing activities		(304,824)		(26,934)
(Decrease) increase in cash and cash equivalents		(289,730)		131,925
Cash and cash equivalents and restricted cash, beginning of period		465,774		250,216
Cash and cash equivalents and restricted cash, end of period	$	176,044	$	382,141

See Notes to Condensed Consolidated Financial Statements.

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NOTE 1 — BASIS OF PRESENTATION AND SIGNIFICANT ACCOUNTING POLICIES

Nature of Operations

W&T Offshore, Inc. (with subsidiaries referred to herein as “W&T” or the “Company”) is an independent oil and natural gas producer with substantially all of its operations offshore in the Gulf of Mexico. The Company is active in the exploration, development and acquisition of oil and natural gas properties. Interests in fields, leases, structures and equipment are primarily owned by the Company and its 100% owned subsidiaries, W & T Energy VI, LLC, Aquasition LLC (“A-I, LLC”), and Aquasition II, LLC (“A-II LLC”), and through a proportionately consolidated interest in Monza Energy LLC (“Monza”).

Basis of Presentation

The accompanying unaudited Condensed Consolidated Financial Statements have been prepared in accordance with U.S. generally accepted accounting principles (“GAAP”) for interim periods and the appropriate rules and regulations of the Securities and Exchange Commission (“SEC”). Accordingly, the condensed consolidated financial statements do not include all of the information and footnote disclosures required by GAAP for complete financial statements for annual periods. In the opinion of management, all adjustments (consisting of normal recurring accruals) considered necessary for a fair presentation have been included.

Operating results for interim periods are not necessarily indicative of the results that may be expected for the entire year. These unaudited condensed consolidated financial statements should be read in conjunction with the consolidated financial statements and notes included in the Company’s 2022 Annual Report on Form 10-K (the “2022 Annual Report”).

Use of Estimates

The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements, the reported amounts of revenues and expenses during the reporting periods and the reported amounts of proved oil and natural gas reserves. Actual results could differ from those estimates.

Summary of Significant Accounting Policies

Revenue and Accounts Receivable – The Company records revenues from the sale of oil, natural gas liquids (“NGLs”) and natural gas based on quantities of production sold to purchasers under short-term contracts (less than twelve months) at market prices when delivery to the customer has occurred, title has transferred, prices are fixed and determinable and collection is reasonably assured. Revenue from the sale of crude oil, NGLs and natural gas is recognized when performance obligations under the terms of the respective contracts are satisfied; this generally occurs with the delivery of oil, NGLs and natural gas to the customer. Each unit of product represents a separate performance obligation, therefore, future volumes are wholly unsatisfied and disclosure of the transaction price allocated to remaining performance obligations is not required.

The Company also has receivables related to joint interest arrangements primarily with mid-size oil and gas companies with a substantial majority of the net receivable balance concentrated in less than ten companies. A loss methodology is used to develop the allowance for credit losses on material receivables to estimate the net amount to be collected. The loss methodology uses historical data, current market conditions and forecasts of future economic conditions. The Company’s maximum exposure at any time would be the receivable balance. Joint interest receivables on the Condensed Consolidated Balance Sheets are presented net of allowance for credit losses of $11.3 million and $12.1 million as of June 30, 2023 and December 31, 2022, respectively.

Employee Retention Credit – Under the Consolidated Appropriations Act of 2021, the Company recognized a $2.2 million employee retention credit during the six months ended June 30, 2023, which is included as a credit to General and administrative expenses in the Condensed Consolidated Statement of Operations.

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Prepaid Expenses and Other Assets – The amounts recorded are expected to be realized within one year and the major categories are presented in the following table (in thousands):


	June 30, 2023		December 31, 2022
Derivatives⁽¹⁾(Note 4)	$	1,778	$	4,954
Unamortized insurance/bond premiums		8,303		6,046
Prepaid deposits related to royalties		6,822		9,139
Prepayments to vendors		1,628		1,767
Prepayments to joint interest partners		2,319		1,717
Debt issue costs		427		687
Other		88		33
Prepaid expenses and other assets	$	21,365	$	24,343

⁽¹⁾

^{Includes closed contracts which have not yet settled.}

Oil and Natural Gas Properties and Other, Net – Oil and natural gas properties and equipment are recorded at cost using the full cost method. There were no amounts excluded from amortization as of the dates presented in the following table (in thousands):


	June 30, 2023		December 31, 2022
Oil and natural gas properties and equipment	$	8,847,421	$	8,813,404
Furniture, fixtures and other		40,224		20,915
Total property and equipment		8,887,645		8,834,319
Less: Accumulated depreciation, depletion, amortization and impairment		(8,149,905)		(8,099,104)
Oil and natural gas properties and other, net	$	737,740	$	735,215

Other Assets (long-term) – The major categories are presented in the following table (in thousands):


	June 30, 2023		December 31, 2022
Right-of-Use assets	$	10,728	$	10,364
Investment in White Cap, LLC		2,721		2,453
Proportional consolidation of Monza (Note 6)		9,909		9,321
Derivatives⁽¹⁾ (Note 4)		17,184		23,236
Other		1,576		2,175
Total other assets (long-term)	$	42,118	$	47,549

⁽¹⁾

^{Includes open contracts.}

Accrued Liabilities – The major categories are presented in the following table (in thousands):


	June 30, 2023		December 31, 2022
Accrued interest	$	13,848	$	8,967
Accrued salaries/payroll taxes/benefits		4,808		15,097
Litigation accruals		56		396
Lease liability		1,045		1,628
Derivatives⁽¹⁾(Note 4)		18,518		46,595
Other		1,048		1,358
Total accrued liabilities	$	39,323	$	74,041

⁽¹⁾

^{Includes closed contracts which have not yet settled.}

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Other Liabilities (long-term) – The major categories are presented in the following table (in thousands):


	June 30, 2023		December 31, 2022
Dispute related to royalty deductions	$	5,250	$	4,937
Derivatives (Note 4)		17,417		43,061
Lease liability		11,709		10,527
Other		665		609
Total other liabilities (long-term)	$	35,041	$	59,134

At-the-Market Equity Offering – On March 18, 2022, the Company filed a prospectus supplement related to the issuance and sale of up to $100,000,000 of shares of common stock under the Company’s “at-the-market” equity offering program (the “ATM Program”). The designated sales agents will be entitled to a placement fee of up to 3.0% of the gross sales price per share sold. During the six months ended June 30, 2023, the Company did not sell any shares in connection with the ATM Program. During the year ended December 31, 2022, the Company sold an aggregate of 2,971,413 shares for an average price of $5.72 per share in connection with the ATM Program and received proceeds, net of commissions and expenses, of $16.5 million.

NOTE 2 — DEBT

The components comprising the Company’s debt are presented in the following table (in thousands):


	June 30, 2023		December 31, 2022
TVPX Loan:
Principal	$	11,575	$	—
Discount		(1,651)
Unamortized debt issuance costs		(267)		—
Total TVPX Loan		9,657		—

Term Loan:
Principal		128,719		147,899
Unamortized debt issuance costs		(3,727)		(4,592)
Total Term Loan		124,992		143,307

Credit Agreement borrowings:		—		—

11.75% Senior Second Lien Notes due 2026:
Principal		275,000		—
Unamortized debt issuance costs		(6,078)		—
Total 11.75% Senior Second Lien Notes due 2026		268,922		—

9.75% Senior Second Lien Notes due 2023:
Principal		—		552,460
Unamortized debt issuance costs		—		(2,330)
Total 9.75% Senior Second Lien Notes due 2023		—		550,130

Less current portion, net		(30,550)		(582,249)
Total long-term debt, net	$	373,021	$	111,188

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Current Portion of Long-Term Debt, Net

As of June 30, 2023, the current portion of long-term debt of $30.6 million represented principal payments due within one year on the TVPX Loan and Term Loan (defined below), net of current unamortized debt issuance costs.

TVPX Loan

On May 15, 2023, the Company acquired a corporate aircraft from a company affiliated with and controlled by W&T’s Chairman, Chief Executive Officer (“CEO”) and President, Tracy W. Krohn. The terms of the transactions were reviewed and approved by the Audit Committee of the Company’s Board of Directors. See Note 12 – Related Party Transactions.

The purchase price of the aircraft was $19.1 million, which was paid using $9.0 million of the Company’s cash on hand and through the assumption of an amortizing loan by TVPX Aircraft Solutions Inc. (the “TVPX Loan”), not in its individual capacity but as owner trustee of the trust which holds title to the aircraft, a wholly owned indirect subsidiary of the Company, as the borrower. At the time of the assumption, the TVPX Loan had an aggregate principal amount of approximately $11.8 million outstanding. The TVPX Loan bears a fixed interest rate of 2.49% per annum for a term of 41 months and requires monthly amortization payments of $91.7 thousand plus accrued interest, which began on May 17, 2023, and a balloon payment of $8.0 million at the end of the loan term. The TVPX Loan is guaranteed by the Company on an unsecured basis. Using current market rates, we determined that the fair market value of the TVPX Loan was $10.1 million at the date of assumption.

The aircraft was purchased as part of a series of transactions pursuant to which the Company restructured the compensation for its Named Executive Officers. Prior to the Company’s purchase of the aircraft, the Company used the aircraft for business purposes, and the CEO also used the aircraft for personal purposes. Both the Company’s use for business purposes and the CEO’s unlimited use for personal purposes were paid for by the Company pursuant to the CEO’s prior employment agreement. In connection with the Company’s efforts to significantly reduce overall executive compensation, including perquisite compensation Mr. Krohn was receiving for personal use of the aircraft, on April 20, 2023, the Company entered into an amendment to the employment agreement with the CEO which requires that the Company be reimbursed for personal use of the aircraft in accordance with the Company’s aircraft use policy.

During the six months ended June 30, 2023, the Company repaid $183.3 thousand of principal outstanding. As of June 30, 2023, the Company had $11.6 million of principal amount outstanding related to the TVPX Loan.

Term Loan (Subsidiary Credit Agreement)

On May 19, 2021, A-I LLC and A-II LLC (collectively, the “Subsidiary Borrowers”), both Delaware limited liability companies and indirect, wholly-owned subsidiaries of the Company, entered into a credit agreement (the “Subsidiary Credit Agreement”) providing for a term loan (the “Term Loan”) in an aggregate principal amount equal to $215.0 million. The Term Loan requires quarterly amortization payments which commenced on September 30, 2021. The Term Loan bears interest at a fixed rate of 7.0% per annum and will mature on May 19, 2028. The Subsidiary Credit Agreement required the Company to enter into certain natural gas swap and put derivative contracts. See Note 4 – Derivative Financial Instruments.

In exchange for the net cash proceeds received by the Subsidiary Borrowers from the Term Loan, the Company assigned to (a) A-I LLC all of its interests in certain oil and gas leasehold interests and associated wells and units located in State of Alabama waters and U.S. federal waters in the offshore Gulf of Mexico, Mobile Bay region (such assets, the “Mobile Bay Properties”) and (b) A-II LLC its interest in certain gathering and processing assets located (i) in State of Alabama waters and U.S. federal waters in the offshore Gulf of Mexico, Mobile Bay region and (ii) onshore near Mobile, Alabama, including offshore gathering pipelines, an onshore crude oil treating and sweetening facility, an onshore gathering pipeline, and associated assets (such assets, the “Midstream Assets”).

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The Term Loan is non-recourse to the Company and any subsidiaries other than the Subsidiary Borrowers and the subsidiary that owns the equity in the Subsidiary Borrowers, and is secured by the first lien security interests in the equity of the Subsidiary Borrowers and a first lien mortgage security interest and mortgages on certain assets of the Subsidiary Borrowers (the Mobile Bay Properties, defined below). See Note 5 – Subsidiary Borrowers for additional information.

During the six months ended June 30, 2023, the Company repaid $19.2 million of principal outstanding. As of June 30, 2023, the Company had $128.7 million in principal amount of the Term Loan outstanding.

Credit Agreement

The Company has entered into a Credit Agreement with Calculus Lending, LLC (“Calculus”), a company affiliated with and controlled by W&T’s Chairman, Chief Executive Officer and President, Tracy W. Krohn, as sole lender under the Credit Agreement (as amended from time to time, the “Credit Agreement”). The Credit Agreement currently has a maturity date of January 3, 2024. Alter Domus (US) LLC serves as the administrative agent under the Credit Agreement. The primary terms and covenants associated with the Credit Agreement as of June 30, 2023, are as follows:

●

$100 million first priority lien secured revolving credit facility, with borrowings limited to a borrowing base of $50.0 million;

●

Outstanding borrowings accrue interest at SOFR plus 6.0% per annum;

●

The Company’s ratio of First Lien Debt (as such term is defined in the Credit Agreement) outstanding under the Credit Agreement on the last day of the most recent quarter to EBITDAX (as such term is defined in the Credit Agreement) for the trailing four quarters must not be greater than 2.50 to 1.00 on the last day of any fiscal quarter commencing with the fiscal quarter ended March 31, 2022;

●

The Company’s ratio of Total Proved PV-10 to First Lien Debt (as such terms are defined in the Credit Agreement) as of the last day of any fiscal quarter commencing with the fiscal quarter ended March 31, 2022, must be equal to or greater than 2.00 to 1.00;

●

The ratio of the Company and its restricted subsidiaries’ consolidated current assets to consolidated current liabilities (subject in each case to certain exceptions and adjustments as set forth in the Credit Agreement) at the last day of any fiscal quarter must be greater than or equal to 1.00 to 1.00;

●

As of the last day of any fiscal quarter commencing with the fiscal quarter ended March 31, 2022, the Company and its restricted subsidiaries on a consolidated basis must pass a “Stress Test” to determine whether certain future net revenues from the Company’s and its restricted subsidiaries’ and certain joint ventures’ oil and gas properties included in the collateral are sufficient to satisfy the aggregate first lien indebtedness under the Credit Agreement assuming the Borrowing Base is 100% funded or fully utilized; and

●

Certain related party transactions are required to meet certain arm’s length criteria; except in each case as specifically permitted or excluded from the covenant under the Credit Agreement.

Availability under the Credit Agreement is subject to redetermination of the borrowing base that may be requested at the discretion of either the lender or the Company in accordance with the Credit Agreement. Any redetermination by the lender to change the borrowing base will result in a similar change in the availability under the Credit Agreement. The Credit Agreement is secured by a first priority lien on substantially all of the Company’s and its guarantor subsidiaries’ assets, excluding those assets of the Subsidiary Borrowers, which liens were released in the Mobile Bay Transaction (as described in Note 5 – Subsidiary Borrowers).

As of June 30, 2023, there were no borrowings outstanding under the Credit Agreement and no borrowings had been incurred under the Credit Agreement during the six months ended June 30, 2023. As of June 30, 2023 and December 31, 2022, the Company had $4.4 million outstanding in letters of credit which have been cash collateralized.

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11.75% Senior Second Lien Notes due 2026

On January 27, 2023, the Company issued and sold $275 million in aggregate principal amount of its 11.75% Senior Second Lien Notes at par with an interest rate of 11.75% per annum that matures on February 1, 2026 (the “11.75% Senior Second Lien Notes”), which are governed under the terms of an indenture (the “Indenture”). Interest on the 11.75% Senior Second Lien Notes is payable in arrears on February 1 and August 1, commencing August 1, 2023. The 11.75% Senior Second Lien Notes will be recorded at their carrying value consisting of principal and unamortized debt issuance costs. The 11.75% Senior Second Lien Notes are secured by second-priority liens on the same collateral that is secured under the Credit Agreement, which does not include the Mobile Bay Properties and the related Midstream Assets. The estimated annual effective interest rate on the 11.75% Senior Second Lien Notes is 12.6%, which includes amortization of deferred interest costs.

Prior to August 1, 2024, the Company may redeem all or any portion of the 11.75% Senior Second Lien Notes at a redemption price equal to 100% of the principal amount of the notes outstanding plus accrued and unpaid interest, if any, to the redemption date, plus the “Applicable Premium” (as defined in the Indenture). In addition, prior to August 1, 2024, the Company may, at its option, on one or more occasions redeem up to 35% of the aggregate original principal amount of the 11.75% Senior Second Lien Notes in an amount not greater than the net cash proceeds from certain equity offerings at a redemption price of 111.750% of the principal amount of the outstanding plus accrued and unpaid interest, if any, to the redemption date.

On and after August 1, 2024, the Company may redeem the 11.75% Senior Second Lien Notes, in whole or in part, at redemption prices (expressed as percentages of the principal amount thereof) equal to 105.875% for the 12-month period beginning August 1, 2024, and 100.000% on August 1, 2025 and thereafter, plus accrued and unpaid interest, if any, to the redemption date. The 11.75% Senior Second Lien Notes are guaranteed by the Guarantors.

The 11.75% Senior Second Lien Notes contain covenants that limit or prohibit the Company’s ability and the ability of certain of its subsidiaries to: (i) make investments; (ii) incur additional indebtedness or issue certain types of preferred stock; (iii) create certain liens; (iv) sell assets; (v) enter into agreements that restrict dividends or other payments from the Company’s subsidiaries to the Company; (vi) consolidate, merge or transfer all or substantially all of the assets of the Company; (vii) engage in transactions with affiliates; (viii) pay dividends or make other distributions on capital stock or subordinated indebtedness; and (ix) create subsidiaries that would not be restricted by the covenants of the Indenture. These covenants are subject to important exceptions and qualifications set forth in the Indenture. In addition, most of the above-described covenants will terminate if both S&P Global Ratings, a division of S&P Global Inc., and Moody’s Investors Service, Inc. assign the 11.75% Senior Second Lien Notes an investment grade rating and no default exists with respect to the 11.75% Senior Second Lien Notes.

Redemption of 9.75% Senior Second Lien Notes due 2023

On October 18, 2018, the Company issued $625.0 million of 9.75% Senior Second Lien Notes due 2023 (the “9.75% Senior Second Lien Notes”), which were issued at par with an interest rate of 9.75% per annum and would have matured on November 1, 2023.

On February 8, 2023, the Company redeemed all of the $552.5 million of aggregate principle outstanding of the 9.75% Senior Second Lien Notes at a redemption price of 100.0%, plus accrued and unpaid interest to the redemption date. The Company used the net proceeds of $270.8 million from the issuance of the 11.75% Senior Second Lien Notes and cash on hand of $296.1 million to fund the redemption.

Covenants

As of June 30, 2023 and for all prior measurement periods presented, the Company was in compliance with all applicable covenants of the Credit Agreement and the Indenture.

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NOTE 3 – FAIR VALUE MEASUREMENTS

Derivative Financial Instruments

Derivative financial instruments are reported in the Condensed Consolidated Balance Sheets using fair value. See Note 4 – Derivative Financial Instruments for additional information on derivative financial instruments. The Company measures the fair value of derivative financial instruments by applying the income approach, using models with inputs that are classified within Level 2 of the valuation hierarchy. The income approach converts expected future cash flows to a present value amount based on market expectations. The inputs used for the fair value measurement of derivative financial instruments are the exercise price, the expiration date, the settlement date, notional quantities, the implied volatility, the discount curve with spreads and published commodity future prices.

The following table presents the fair value of the Company’s derivative financial instruments (in thousands):


	June 30, 2023		December 31, 2022
Assets:
Derivative instruments - current	$	1,778	$	4,954
Derivative instruments - long-term		17,184		23,236

Liabilities:
Derivative instruments - current		18,518		46,595
Derivative instruments - long-term		17,417		43,061

Debt Instruments

The following table presents the net value and fair value of the Company’s debt (in thousands):


	June 30, 2023				December 31, 2022
	Net Value		Fair Value		Net Value		Fair Value
Liabilities:
TVPX Loan	$	9,657	$	9,977	$	—	$	—
Term Loan		124,992		120,965		143,307		139,056
11.75% Senior Second Lien Notes due 2026		268,922		275,303		—		—
9.75% Senior Second Lien Notes due 2023		—		—		550,130		544,902
Total	$	403,571	$	406,245	$	693,437	$	683,958

The fair value of the TVPX Loan and the Term Loan were measured using a discounted cash flows model and current market rates. The fair value of the 11.75% Senior Second Lien Notes and 9.75% Senior Second Lien Notes were measured using quoted prices, although the market is not a highly liquid market. The fair value of debt was classified as Level 2 within the valuation hierarchy.

NOTE 4 — DERIVATIVE FINANCIAL INSTRUMENTS

W&T’s market risk exposure relates primarily to commodity prices. The Company attempts to mitigate a portion of its commodity price risk and stabilize cash flows associated with sales of oil and natural gas production through the use of oil and natural gas swaps, costless collars, sold calls and purchased puts. The Company is exposed to credit loss in the event of nonperformance by the derivative counterparties; however, the Company currently anticipates that the derivative counterparties will be able to fulfill their contractual obligations. The Company is not required to provide additional collateral to the derivative counterparties and does not require collateral from the derivative counterparties.

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W&T has elected not to designate commodity derivative contracts for hedge accounting. Accordingly, commodity derivatives are recorded on the Condensed Consolidated Balance Sheets at fair value with settlements of such contracts, and changes in the unrealized fair value, recorded as Derivative (gain) loss on the Condensed Consolidated Statements of Operations in each period presented. The cash flows of all commodity derivative contracts are included in Net cash provided by operating activities on the Condensed Consolidated Statements of Cash Flows.

The natural gas contracts are based off the Henry Hub prices, which is quoted off the New York Mercantile Exchange (“NYMEX”).

The following table reflects the contracted volumes and weighted average prices under the terms of the Company’s open derivative contracts as of June 30, 2023:



		Average
	Instrument	Daily	Total	Weighted		Weighted		Weighted
Period	Type	Volumes	Volumes	Strike Price		Put Price		Call Price

Natural Gas - Henry Hub (NYMEX)		(MMbtu)⁽¹⁾	(MMbtu)⁽¹⁾		($/MMbtu)⁽¹⁾		($/MMbtu)⁽¹⁾		($/MMbtu)⁽¹⁾
July 2023 - Dec 2023	calls	35,288	12,880,000	$	—	$	—	$	7.50
Jan 2024 - Dec 2024	calls	65,000	23,790,000	$	—	$	—	$	6.13
Jan 2025 - Mar 2025	calls	62,000	5,580,000	$	—	$	—	$	5.50
July 2023 - Dec 2023⁽²⁾	swaps	36,164	13,200,000	$	2.43	$	—	$	—
Jan 2024 - Dec 2024⁽²⁾	swaps	65,574	24,000,000	$	2.46	$	—	$	—
Jan 2025 - Mar 2025⁽²⁾	swaps	63,333	5,700,000	$	2.72	$	—	$	—
Apr 2025 - Dec 2025⁽²⁾	puts	62,182	17,100,000	$	—	$	2.27	$	—
Jan 2026 - Dec 2026⁽²⁾	puts	55,890	20,400,000	$	—	$	2.35	$	—
Jan 2027 - Dec 2027⁽²⁾	puts	52,603	19,200,000	$	—	$	2.37	$	—
Jan 2028 - Apr 2028⁽²⁾	puts	49,587	6,000,000	$	—	$	2.50	$	—

⁽¹⁾	^{MMbtu – Million British Thermal Units}

⁽²⁾	^{These contracts were entered into by the Company’s wholly owned subsidiary, A-I LLC, in conjunction with the Term Loan (see}^{Note 5 – Subsidiary Borrowers).}

Financial Statement Presentation

The following fair value of derivative financial instruments amounts were recorded in the Condensed Consolidated Balance Sheets (in thousands):


	June 30, 2023		December 31, 2022
Prepaid expenses and other current assets	$	1,778	$	4,954
Other assets (long-term)		17,184		23,236
Accrued liabilities		18,518		46,595
Other liabilities (long-term)		17,417		43,061

Although the Company has master netting arrangements with its counterparties, the amounts recorded on the Condensed Consolidated Balance Sheets are on a gross basis.

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Changes in the fair value and settlements of contracts are recorded on the Condensed Consolidated Statements of Operations as Derivative (gain) loss, net. The impact of commodity derivative contracts on the Condensed Consolidated Statements of Operations were as follows (in thousands):


	Three Months Ended June 30,				Six Months Ended June 30,
	2023		2022		2023		2022
Realized loss (gain)⁽¹⁾	$	300	$	(79,667)	$	530	$	(35,973)
Unrealized (gain) loss		(1,129)		70,813		(40,599)		107,116
Derivative (gain) loss, net	$	(829)	$	(8,854)	$	(40,069)	$	71,143

(1)

^{The three and six months ended June 30, 2022 includes the effect of the}^$138.0^{million realized gain related to the monetization of certain natural gas call contracts through restructuring of strike prices.}

Cash payments on commodity derivative contract settlements, net, are included within Net cash provided by operating activities on the Condensed Consolidated Statements of Cash Flows and were as follows (in thousands):


	Six Months Ended June 30,
	2023		2022
Derivative (gain) loss, net	$	(40,069)	$	71,143
Derivative cash (receipts) payments, net⁽¹⁾		(4,427)		70,227
Derivative cash premium payments, net		—		(46,111)

(1)

^{The six months ended June 30, 2022 includes}^$105.3^{million of net cash receipts related to the monetization of certain natural gas call contracts through restructuring of strike prices.}

NOTE 5 — SUBSIDIARY BORROWERS

On May 19, 2021, the Subsidiary Borrowers, entered into the Subsidiary Credit Agreement providing for the Term Loan in an aggregate principal amount equal to $215.0 million. Proceeds of the Term Loan were used by the Subsidiary Borrowers to (i) fund the acquisition of the Mobile Bay Properties and the Midstream Assets from the Company and (ii) pay fees, commissions and expenses in connection with the transactions contemplated by the Subsidiary Credit Agreement and the other related loan documents, including to enter into certain swap and put derivative contracts described in more detail under Note 4 – Derivative Financial Instruments, of this Quarterly Report on Form 10-Q.

The Subsidiary Borrowers are wholly-owned subsidiaries of the Company; however, the assets of the Subsidiary Borrowers are not available to satisfy the debt or contractual obligations of any other entities, including debt securities or other contractual obligations of the Company, and the Subsidiary Borrowers do not bear any liability for the indebtedness or other contractual obligations of any other entities, and vice versa.

During the year ended December 31, 2022, the Subsidiary Borrowers paid cash distributions to W&T of $30.2 million. During the six months ended June 30, 2023, no such distributions were paid.

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Consolidation and Carrying Amounts

The following table presents the amounts recorded by W&T on the Condensed Consolidated Balance Sheets related to the consolidation of the Subsidiary Borrowers and the subsidiary that owns the equity of the Subsidiary Borrowers (in thousands):


	June 30, 2023		December 31, 2022
Assets:
Cash and cash equivalents	$	5,899	$	21,764
Receivables:
Oil and natural gas sales		18,411		37,344
Joint interest, net		(27,400)		(5,760)
Prepaid expenses and other assets		125		417
Oil and natural gas properties and other, net		289,959		280,649
Other assets		11,486		8,473
Liabilities:
Accounts payable		8,996		27,387
Undistributed oil and natural gas proceeds		3,625		7,930
Accrued liabilities		19,036		45,102
Current portion of long-term debt		30,074		32,119
Long-term debt, net		94,918		111,188
Asset retirement obligations		66,136		61,138
Other liabilities		22,020		47,398

The following table presents the amounts recorded by W&T in the Condensed Consolidated Statement of Operations related to the consolidation of the operations of the Subsidiary Borrowers and the subsidiary that owns the equity of the Subsidiary Borrowers (in thousands):


	Three Months Ended June 30,				Six Months Ended June 30,
	2023		2022		2023		2022
Total revenues	$	25,437	$	76,846	$	46,560	$	124,361
Total operating expenses		30,443		18,385		50,490		33,185
Interest expense, net		3,229		3,658		5,411		8,436
Derivative (gain) loss, net		(6,012)		35,888		(52,389)		132,046

NOTE 6 — JOINT VENTURE DRILLING PROGRAM

In March 2018, W&T and two other initial members formed and initially funded Monza, which jointly participates with the Company in the exploration, drilling and development of certain drilling projects (the “Joint Venture Drilling Program”) in the Gulf of Mexico. Subsequent to the initial closing, additional investors joined as members of Monza during 2018 and total commitments by all members, including W&T’s commitment to fund its retained interest in Monza projects held outside of Monza, was $361.4 million. W&T contributed 88.94% of its working interest in certain identified undeveloped drilling projects to Monza and retained 11.06% of its working interest. The Joint Venture Drilling Program is structured so that W&T initially receives an aggregate of 30.0% of the revenues less expenses, through the direct ownership from the retained working interest in the Monza projects and the Company’s indirect interest through its interest in Monza, for contributing 20.0% of the estimated total well costs plus associated leases and providing access to available infrastructure at agreed-upon rates. Any exceptions to this structure are approved by the Monza board of directors.

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The members of Monza are third-party investors, W&T and an entity owned and controlled by Tracy W. Krohn, the Company’s Chairman, Chief Executive Officer and President. The entity affiliated with the Company’s CEO invested as a minority investor on the same terms and conditions as the third-party investors, and its investment is limited to 4.5% of total invested capital within Monza, and made a capital commitment to Monza of $14.5 million.

Monza is an entity separate from any other entity with its own separate creditors who will be entitled, upon its liquidation, to be satisfied out of Monza’s assets prior to any value in Monza becoming available to holders of its equity. The assets of Monza are not available to pay creditors of the Company and its affiliates.

Through June 30, 2023, ten wells have been completed since the inception of the Joint Venture Drilling Program. W&T is the operator for eight of the ten wells completed through June 30, 2023.

Since inception through June 30, 2023, members of Monza made partner capital contributions, including W&T’s contributions of working interest in the drilling projects, to Monza totaling $302.4 million and received cash distributions totaling $204.7 million. Since inception through June 30, 2023, W&T made total capital contributions, including the contributions of working interest in the drilling projects, to Monza totaling $68.2 million and received cash distributions totaling $48.3 million.

Consolidation and Carrying Amounts

W&T’s interest in Monza is considered to be a variable interest that is proportionally consolidated. Through June 30, 2023, there have been no events or changes that would cause a redetermination of the variable interest status. W&T does not fully consolidate Monza because the Company is not considered the primary beneficiary of Monza.

The following table presents the amounts recorded by W&T on the Condensed Consolidated Balance Sheets related to the consolidation of the proportional interest in Monza’s operations (in thousands):


	June 30, 2023		December 31, 2022
Working capital	$	1,191	$	2,515
Oil and natural gas properties and other, net		34,516		37,260
Asset retirement obligations		518		467
Other assets		9,909		11,571

As required, W&T may call on Monza to provide cash to fund its portion of certain Joint Venture Drilling Program projects in advance of capital expenditure spending, and the unused balances as of June 30, 2023 and December 31, 2022 were $2.8 million and $2.9 million, respectively, which are included in the Condensed Consolidated Balance Sheets in Advances from joint interest partners.

The following table presents the amounts recorded by W&T in the Condensed Consolidated Statement of Operations related to the consolidation of the proportional interest in Monza’s operations (in thousands):


	Six Months Ended June 30,
	2023		2022
Total revenues	$	6,018	$	16,615
Total operating expenses		4,623		7,368
Interest income		104		—

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NOTE 7 — ASSET RETIREMENT OBLIGATIONS

AROs represent the estimated present value of the amount incurred to plug, abandon and remediate the Company’s properties at the end of their productive lives. A summary of the changes to ARO is as follows (in thousands):


	Six Months Ended June 30,
	2023
Asset retirement obligations, beginning of period	$	466,430
Liabilities settled		(11,841)
Accretion expense		15,227
Liabilities incurred		113
Revisions of estimated liabilities		10,903
Asset retirement obligations, end of period		480,832
Less: Current portion		(37,763)
Long-term	$	443,069

NOTE 8 — SHARE-BASED AWARDS AND CASH BASED AWARDS

On June 16, 2023, the 2023 Incentive Compensation Plan (the “2023 Plan”) was approved by the Company’s shareholders. The 2023 Plan is effective June 16, 2023, and the Company will no longer grant awards pursuant to the W&T Offshore, Inc. Amended and Restated Incentive Compensation Plan, as amended from time to time, (the “Prior Plan”) or the 2004 Directors Compensation Plan, as amended from time to time. Under the 2023 Plan, the Company may issue, subject to the approval of the Board of Directors, stock options, stock appreciation rights, restricted stock, restricted stock units, performance awards, stock awards, dividend equivalents, other stock-based awards, performance units or shares, cash awards, substitute awards or any combination of the foregoing to eligible employees, non-employee directors, and consultants. Any awards granted prior to the effective date of the 2023 Plan are considered to have been granted under the Prior Plan.

Share-Based Awards to Employees

Restricted Stock Units (“RSUs”) – On June 5, 2023, the Company granted RSUs under the Prior Plan to certain employees. RSUs outstanding as of June 30, 2023 relate to the 2023, 2022, and 2021 grants. The 2023 RSUs granted are a long-term compensation component, subject to service conditions, with one-third of the award vesting each year on June 5, 2024, 2025 and 2026, respectively.

A summary of activity related to RSUs during the six months ended June 30, 2023 is as follows:


		Weighted
		Average
	Restricted	Grant Date Fair
	Stock Units	Value Per Unit
Nonvested, beginning of period	1,221,461	$	5.76
Granted	1,527,221		4.09
Vested	(486,134)		5.62
Forfeited	(80,911)		5.97
Nonvested, end of period	2,181,637		4.61

Performance Share Units (“PSUs”) – On June 5, 2023, the Company granted PSUs under the Prior Plan that are eligible to vest based on continued employment and the Company’s total shareholder return (“TSR”) ranking against peer companies’ TSR over a three-year performance period, which ends on December 31, 2025. PSUs outstanding as of June 30, 2023 relate to the 2023, 2022 and 2021 grants.

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A summary of activity related to PSUs during the six months ended June 30, 2023 is as follows:


		Weighted
		Average
	Performance	Grant Date Fair
	Share Units	Value Per Unit
Nonvested, beginning of period	1,502,239	$	9.78
Granted	1,187,638		4.87
Vested	(10,705)		7.80
Forfeited	(188,307)		10.05
Nonvested, end of period	2,490,865		7.43

The following table summarizes the assumptions used in the Monte Carlo simulations to calculate the fair value of the absolute TSR PSUs granted at the date indicated:


	2023 Grant Date
	June 5, 2023
Expected term for performance period (in years)		2.6
Expected volatility		76.1	%
Risk-free interest rate		4.2	%
Fair value (in thousands)	$	5,694

Share-Based Awards to Non-Employee Directors

The Company may from time-to-time issue awards to non-employee directors pursuant to the 2023 Plan. There were no awards granted to non-employee directors during the six months ended June 30, 2023. Restricted shares vested during the six months ended June 30, 2023 relate to 2022 restricted shares issued to the non-employee directors.

A summary of activity related to restricted shares during the six months ended June 30, 2023 is as follows:


		Weighted
		Average
		Grant Date
	Restricted	Fair Value
	Shares	Per Share
Nonvested, beginning of period	42,426	$	4.95
Vested	(42,426)		4.95
Nonvested, end of period	—	$	—

Share-Based Compensation Expense

Compensation costs for share-based payments are recognized over the requisite service period. A summary of compensation expense under share-based payment arrangements is as follows (in thousands):


	Three Months Ended June 30,				Six Months Ended June 30,
	2023		2022		2023		2022
Restricted stock units	$	945	$	1,360	$	1,443	$	1,610
Performance share units		1,124		598		2,496		803
Restricted Shares		18		56		70		121
Total	$	2,087	$	2,014	$	4,009	$	2,534

Cash-Based Incentive Compensation

In addition to share-based compensation, short-term cash-based incentive awards were granted under the Plan to all eligible employees during the six months ended June 30, 2023. The short-term cash-based incentive awards granted in 2022 were paid in March 2023.

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Share-Based Awards and Cash-Based Awards Compensation Expense

A summary of compensation expense related to share-based awards and cash-based awards is as follows (in thousands):


	Three Months Ended June 30,				Six Months Ended June 30,
	2023		2022		2023		2022
Share-based compensation included in:
General and administrative expenses	$	2,087	$	2,014	$	4,009	$	2,534
Cash-based incentive compensation included in:
Lease operating expense⁽¹⁾		321		206		1,568		462
General and administrative expenses⁽¹⁾		899		646		6,869		2,603
Total charged to operating income (loss)	$	3,307	$	2,866	$	12,446	$	5,599

(1)

^{Includes adjustments of accruals to actual payments.}

NOTE 9 — INCOME TAXES

Tax Expense (Benefit) and Tax Rate

For the three months ended June 30, 2023, the Company recognized income tax expense of $3.0 million. Primarily as a result of changes in our valuation allowance on our deferred tax assets, our effective tax rate for the three months ended June 30, 2023 is not meaningful. For the three months ended June 30, 2022, the Company recognized income tax expense of $31.1 million for an effective tax rate of 20.1%.

For the six months ended June 30, 2023, the Company recognized income tax expense of $11.6 million for an effective tax rate of 45.6%. For the six months ended June 30, 2022, the Company recognized income tax expense of $30.4 million for an effective tax rate of 20.1%. For the three and six months ended June 30, 2023, the Company’s effective tax rate differed from the statutory Federal tax rate primarily by the impact of state income taxes, nondeductible compensation, and adjustments to the valuation allowance. For the three and six months ended June 30, 2022, the Company’s effective tax rate differed from the statutory Federal tax rate primarily by the impact of state income taxes and adjustments to the valuation allowance.

Calculation of Interim Provision for Income Tax.

Historically, the Company has calculated the provision for income taxes during interim reporting periods by applying an estimate of the annual effective tax rate for the full year to income (loss) for the interim period. In the second quarter of 2023, the Company concluded that it could not calculate a reliable estimate of the annual effective tax rate. Accordingly, the Company computed the effective tax rate for the six-month period ending June 30, 2023 using actual results.

Valuation Allowance

Deferred tax assets are recorded related to net operating losses and temporary differences between the book and tax basis of assets and liabilities expected to produce tax deductions in future periods. The realization of these assets depends on recognition of sufficient future taxable income in specific tax jurisdictions in which those temporary differences or net operating losses are deductible. In assessing the need for a valuation allowance on deferred tax assets, the Company considers whether it is more likely than not that some portion or all of them will not be realized.

As of June 30, 2023 and December 31, 2022, the valuation allowance was $19.8 million and $15.3 million, respectively, and relates primarily to state net operating losses and the disallowed interest expense limitation carryover.

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Income Taxes Receivable, Refunds and Payments

As of June 30, 2023, the Company has a federal income tax receivable of $1.7 million and state income tax receivable of $0.2 million. As of December 31, 2022, the Company did not have any outstanding current income taxes receivable. During the three and six months ended June 30, 2023, the Company did not receive any income tax refunds and made federal income tax payments of $2.2 million and state income tax payments of $0.3 million. During the three and six months ended June 30, 2022, the Company did not receive any income tax refunds or make any income tax payments of significance.

The tax years 2019 through 2022 remain open to examination by the tax jurisdictions to which the Company is subject.

NOTE 10 — EARNINGS PER SHARE

The following table presents the calculation of basic and diluted (loss) earnings per common share (in thousands, except per share amounts):


	Three Months Ended June 30,				Six Months Ended June 30,
	2023		2022		2023		2022
Net (loss) income	$	(12,109)	$	123,436	$	13,896	$	120,979
Less portion allocated to nonvested shares		—		—		243		—
Net (loss) income allocated to common shares	$	(12,109)	$	123,436	$	13,653	$	120,979

Weighted average common shares outstanding - basic		146,452		143,020		146,435		142,981
Dilutive effect of securities		—		1,505		2,610		1,113
Weighted average common shares outstanding - diluted		146,452		144,525		149,045		144,094
Earnings per common share:
Basic	$	(0.08)	$	0.86	$	0.09	$	0.85
Diluted		(0.08)		0.85		0.09		0.84

Shares excluded due to being anti-dilutive (weighted average)		2,909		—		—		—

NOTE 11 — CONTINGENCIES

Appeal with the Office of Natural Resources Revenue (“ONRR”) – In 2009, W&T recognized allowable reductions of cash payments for royalties owed to the ONRR for transportation of their deepwater production through subsea pipeline systems owned by the Company. In 2010, the ONRR audited calculations and support related to this usage fee, and ONRR notified the Company that they had disallowed approximately $4.7 million of the reductions taken. The Company recorded a reduction to other revenue in 2010 to reflect this disallowance with the offset to a liability reserve; however, the Company disagrees with the position taken by the ONRR. W&T filed an appeal with the ONRR, which ultimately led to the Company posting a bond in the amount of $7.2 million and cash collateral of $6.9 million with the surety in order to appeal the Interior Board of Land Appeals decision. The cash collateral held by the surety was subsequently returned to the Company during the first quarter of 2020. The Company has continued to pursue its legal rights and, at present, the case is in front of the U.S. District Court for the Eastern District of Louisiana where both parties have filed cross-motions for summary judgment and opposition briefs. W&T has filed a Reply in support of its Motion for Summary Judgment and the government has in turn filed its Reply brief. With briefing now completed, the Company is waiting for the district court’s ruling on the merits. In compliance with the ONRR’s request for W&T to periodically increase the surety posted in the appeal to cover pre- and post-judgement interest, the sum of the bond posted is $8.9 million as of June 30, 2023.

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Civil Penalties – In January 2021, W&T executed a Settlement Agreement with the Bureau of Safety and Environmental Enforcement (“BSEE”) which resolved nine pending civil penalties issued by BSEE. The civil penalties pertained to Incidents of Non-Compliance (“INC”) issued by BSEE alleging regulatory non-compliance at separate offshore locations on various dates between July 2012 and January 2018, with the proposed civil penalty amounts totaling $7.7 million. Under the Settlement Agreement, W&T agreed to pay a total of $720,000 in three annual installments. The first, second and final installments were paid in March 2021, March 2022 and February 2023, respectively.

Contingent Decommissioning Obligations – The Company may be subject to retained liabilities with respect to certain divested property interests by operation of law. Certain counterparties in past divestiture transactions or third parties in existing leases that have filed for bankruptcy protection or undergone associated reorganizations may not be able to perform required abandonment obligations. Due to operation of law, W&T may be required to assume decommissioning obligations for those interests. The Company may be held jointly and severally liable for the decommissioning of various facilities and related wells. W&T no longer owns these assets nor are they related to current operations.

During 2021, as a result of the declaration of bankruptcy by a third party that is the indirect successor in title to certain offshore interests that were previously divested by the Company, W&T recorded an initial contingent loss accrual of $4.5 million related to anticipated decommissioning obligations, which was reflected in Other (income) expense, net on the Condensed Consolidated Statements of Operations in the period recorded. The Company reassessed the recorded contingent loss related to the anticipated decommissioning obligations throughout 2022, and as of December 31, 2022, the total loss contingency recorded was $20.4 million. The additional $15.9 million recorded in 2022 was reflected in Other (income) expense, net on the Condensed Consolidated Statements of Operations in the period recorded. During the six months ended June 30, 2023, the Company incurred $3.4 million in costs related to these decommissioning obligations and reduced the liability accordingly. As of June 30, 2023, the remaining loss contingency recorded related to the anticipated decommissioning obligations was $17.0 million.

Although it is reasonably possible that the Company could receive additional state or federal decommissioning orders in the future or be notified of defaulting third parties in existing leases, the Company cannot predict with certainty, if, how or when such orders or notices will be resolved or estimate a possible loss or range of loss that may result from such orders. However, the Company could incur judgments, enter into settlements or revise the Company’s opinion regarding the outcome of certain notices or matters, and such developments could have a material adverse effect on the Company’s results of operations in the period in which the amounts are accrued and the Company’s cash flows in the period in which the amounts are paid. To the extent that the Company does incur costs associated with these properties in future periods, W&T intends to seek contribution from other parties that owned an interest in the facilities.

Other Claims – W&T is a party to various pending or threatened claims and complaints seeking damages or other remedies concerning commercial operations and other matters in the ordinary course of its business. In addition, claims or contingencies may arise related to matters occurring prior to the Company’s acquisition of properties or related to matters occurring subsequent to the Company’s sale of properties. In certain cases, W&T has indemnified the sellers of properties acquired, and in other cases, W&T has indemnified the buyers of properties sold. The Company is also subject to federal and state administrative proceedings conducted in the ordinary course of business including matters related to alleged royalty underpayments on certain federal-owned properties. Although W&T can give no assurance about the outcome of pending legal and federal or state administrative proceedings and the effect such an outcome may have, the Company believes that any ultimate liability resulting from the outcome of such proceedings, to the extent not otherwise provided for or covered by insurance, will not have a material adverse effect on the consolidated financial position, results of operations or liquidity of the Company.

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NOTE 12 — RELATED PARTY TRANSACTIONS

On May 15, 2023, the Company acquired a corporate aircraft from a company affiliated with and controlled by W&T’s CEO. The purchase price of the aircraft was $19.1 million, which was paid using $9.0 million of cash on hand and through the assumption of the TVPX Loan, which had a fair market value of $10.1 million on the date of assumption. The terms of this transaction were reviewed and approved by the Audit Committee of the Company’s Board of Directors. See Note 2 – Debt for additional information.

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Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations

The following discussion and analysis should be read in conjunction with our unaudited Condensed Consolidated Financial Statements and the notes to those financial statements included in Part I, Item 1 of this Quarterly Report, as well as our audited Consolidated Financial Statements and the notes thereto in 2022 Annual Report and the related Management’s Discussion and Analysis of Financial Condition and the Results of Operations included in Part II, Item 7 of our 2022 Annual Report. Unless otherwise indicated or the context otherwise requires, references in this Quarterly Report to “us,” “we,” “our,” “W&T” or the “Company” are to W&T Offshore, Inc. and its wholly owned subsidiaries.

Cautionary Note Regarding Forward-Looking Statements

The information in this Quarterly Report includes “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”). All statements, other than statements of historical fact included in this Quarterly Report, regarding our strategy, future operations, financial position, estimated revenues and losses, projected costs, prospects, plans and objectives of management are forward-looking statements. These forward-looking statements are based on certain assumptions and analyses made by us in light of our experience and perception of historical trends, current conditions, expected future developments and other factors we believe are appropriate under the circumstances. Although we believe that these forward-looking statements are based upon reasonable assumptions, they are subject to several risks and uncertainties and are made in light of information currently available to us. If the risks or uncertainties materialize or the assumptions prove incorrect, our results may differ materially from those expressed or implied by such forward-looking statements and assumptions. When used in this Quarterly Report, the words “could,” “believe,” “anticipate,” “intend,” “estimate,” “expect,” “project,” “forecast,” “may,” “objective,” “plan,” and similar expressions are intended to identify forward-looking statements, although not all forward-looking statements contain such identifying words. Readers are cautioned not to place undue reliance on forward-looking statements, which speak only as of the date hereof. We assume no obligation, nor do we intend, to update these forward-looking statements, unless required by law.

The information included in this Quarterly Report includes forward-looking statements that involve risks and uncertainties that could materially affect our expected results of operations, liquidity, cash flows and business prospects. Such statements specifically include our expectations as to our future financial position, liquidity, cash flows, results of operations and business strategy, potential acquisition opportunities, other plans and objectives for operations, capital for sustained production levels, expected production and operating costs, reserves, hedging activities, capital expenditures, return of capital, improvement of recovery factors and other guidance. Actual results may differ from anticipated results, sometimes materially, and reported results should not be considered an indication of future performance. For any such forward-looking statement that includes a statement of the assumptions or bases underlying such forward-looking statement, we caution that, while we believe such assumptions or bases to be reasonable and make them in good faith, assumed facts or bases almost always vary from actual results, sometimes materially. Known material risks that may affect our financial condition and results of operations are discussed in Part I, Item 1A, Risk Factors, and market risks are discussed in Part II, Item 7A, Quantitative and Qualitative Disclosures About Market Risk, of our 2022 Annual Report, and may be discussed or updated from time to time in subsequent reports filed with the SEC.

Reserve engineering is a process of estimating underground accumulations of crude oil, NGLs and natural gas that cannot be measured in an exact manner. The accuracy of any reserve estimate depends on the quality of available data, the interpretation of such data, and the price and cost assumptions made by reservoir engineers. In addition, the results of drilling, testing, and production activities, or changes in commodity prices, may justify revisions of estimates that were made previously. If significant, such revisions would change the schedule of any further production and development drilling. Accordingly, reserve estimates may differ significantly from the quantities of crude oil, NGLs and natural gas that are ultimately recovered.

All forward-looking statements, expressed or implied, included in this Quarterly Report are expressly qualified in their entirety by this cautionary statement. This cautionary statement should also be considered in connection with any subsequent written or oral forward-looking statements that we or persons acting on our behalf may issue.

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Overview

We are an independent oil and natural gas producer, active in the exploration, development and acquisition of oil and natural gas properties in the Gulf of Mexico. As of June 30, 2023, we hold working interests in 46 producing offshore fields in federal and state waters (which include 38 fields in federal waters and 8 in state waters). We currently have under lease approximately 578,000 gross acres (419,000 net acres) spanning across the outer continental shelf (“OCS”) off the coasts of Louisiana, Texas, Mississippi and Alabama, with approximately 8,000 gross acres in Alabama state waters, 416,500 gross acres on the conventional shelf and approximately 153,500 gross acres in the deepwater. A majority of our daily production is derived from wells we operate. Our interests in fields, leases, structures and equipment are primarily owned by W&T Offshore, Inc. and our wholly-owned subsidiaries, Aquasition LLC, Aquasition II LLC and, W&T Energy VI, LLC, each of which are Delaware limited liability companies, and through our proportionately consolidated interest in Monza.

Known Trends and Uncertainties

Volatility in Oil, NGL and Natural Gas Prices – Our financial condition, cash flow and results of operations are significantly affected by the volume of our crude oil, NGLs and natural gas production and the prices that we receive for such production. Our realized sales prices received for our crude oil, NGLs and natural gas production are affected by many factors outside of our control, including changes in market supply and demand, which are impacted by weather conditions, pipeline capacity constraints, inventory storage levels, domestic production activities and political issues, and international geopolitical and economic events.

WTI crude oil prices and NYMEX Henry Hub natural gas prices have decreased following the surge in prices during 2022, closing the second quarter at $70.66 per barrel and $2.48 per Mcf, respectively. The U.S. Energy Information Administration (“EIA”) published its latest Short-Term Energy Outlook on July 11, 2023. The EIA expects the WTI spot price average to remain relatively flat in the third quarter of 2023 at $73.32 per barrel as compared to the second quarter 2023 average of $73.49 per barrel. The EIA expects the average Henry Hub spot price to increase during the third quarter of 2023 to $2.74 per Mcf as compared to the second quarter 2023 average of $2.25 per Mcf.

In June 2023 the Organization of the Petroleum Exporting Countries (“OPEC”) and Russia (together with OPEC, collectively “OPEC Plus”) announced that prior production cuts of over 3.6 million barrels per day, which were valid until the end of 2023, had been extended until the end of 2024. OPEC also announced plans to further reduce production targets by an additional 1.4 million barrels per day beginning in January 2024. Saudi Arabia also announced plans in June to reduce the country’s output by over 1.0 million barrels per day beginning in July 2023. Despite these OPEC Plus production cuts, the EIA expects that the global oil markets will see an overall increase in oil supply during 2023 primarily because of growth from non-OPEC producers. In addition, increasing risk in the U.S. and global banking sectors creates uncertainty about macroeconomic conditions and their potential effects on oil demand growth, which has the potential to result in lower oil prices. These shifts in OPEC Plus production levels as well as the Russia-Ukraine war and related sanctions, and overall indicators of slowing global economic growth, continue to contribute to a high level of uncertainty surrounding energy supply and demand, putting additional pressure on commodity prices.

Rising Interest Rates and Inflation of Cost of Goods, Services and Personnel – Due to the cyclical nature of the oil and gas industry, fluctuating demand for oilfield goods and services can put pressure on the pricing structure within our industry. As commodity prices rise, the cost of oilfield goods and services generally also increase, while during periods of commodity price declines, oilfield costs typically lag and do not adjust downward as fast as oil prices do. Continued inflationary pressures and increased commodity may also result in increases to the costs of our oilfield goods, services and personnel, which would in turn cause our capital expenditures and operating costs to rise.

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The United States has experienced a rise in inflation since October 2021. Inflation peaked during mid-2022 at 9.1% but has been gradually declining since the second half of 2022 according to the Consumer Price Index. As of June 2023, the annual inflation rate had slowed to 3.0% according to the Consumer Price Index. Though inflation is currently on the decline, these inflationary pressures have caused the Federal Reserve to tighten monetary policy by approving a series of increases to the Federal Funds Rate. On July 26, 2023, the Federal Reserve increased the Federal Funds Rate by another 0.25 percentage points, its eleventh hike since March 2022. This latest rate hike brought the Federal Reserve benchmark rate range to 5.25% to 5.50%. If inflation were to continue to rise, it is possible the Federal Reserve would continue to take action they deem necessary to bring inflation down and to ensure price stability, including further rate increases, which could have the effects of raising the cost of capital and depressing economic growth, either or both of which could negatively impact our business.

As a result of these factors, we cannot accurately predict future commodity prices and, therefore, we cannot determine with any degree of certainty what effect increases or decreases in these prices will have on our drilling program, production volumes or revenues.

Planned and Unplanned Downtime – We are subject to downtime events impacting production, transportation, gathering and processing of our production. Unplanned or planned downtime may be caused, for example, by certain regulatory requirements and inspections or third-party pipeline maintenance. During such downtime, our operating income is negatively impacted. During the first quarter of 2023, our production was temporarily impacted by planned maintenance at Mobile Bay and unplanned downtime at other non-operated fields. During the second quarter of 2023, our production was negatively impacted by unplanned downtime due to third-party pipeline maintenance and production downtime at non-operated fields.

Bureau of Ocean Energy Management (“BOEM”) Matters – In order to cover the various decommissioning obligations of lessees on the OCS, the BOEM generally requires that lessees post some form of acceptable financial assurance that such obligations will be met, such as surety bonds. The cost of such bonds or other financial assurance can be substantial, and we can provide no assurance that we can continue to obtain bonds or other surety in all cases. The Department of Interior is reviewing many BOEM regulations and proposed a rule in June 2023 that would revise BOEM’s criteria for determining whether lessees are required to provide supplemental financial insurance. Accordingly, we may be subject to additional financial assurance requirements in the future. As of the filing date of this Quarterly Report, we are in compliance with our financial assurance obligations to the BOEM and have no outstanding BOEM orders related to supplemental financial assurance obligations. We and other offshore Gulf of Mexico producers may, in the ordinary course of business, receive requests or demands in the future for financial assurances from the BOEM.

Surety Bond Collateral – Some of the sureties that provide us surety bonds used for supplemental financial assurance purposes or bonds associated with our appeals of Department of the Interior’s orders or demands have on occasion requested and received collateral from us, and may request additional collateral from us in the future, which could be significant and materially impact our liquidity. In addition, pursuant to the terms of our agreements with various sureties under our existing bonds or under any additional bonds we may obtain, we are required to post collateral at any time, on demand, at the surety’s discretion. No additional demands were made to us by sureties during the six months ended June 30, 2023 and we do not have surety bond collateral outstanding as of the filing date of this Quarterly Report. The issuance of any additional surety bonds or other security to satisfy future BOEM orders, collateral requests from surety bond providers, and collateral requests from other third parties may require the posting of cash collateral, which may be significant, and may require the creation of escrow accounts.

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Results of Operations

Three Months Ended June 30, 2023 Compared to the Three Months Ended June 30, 2022

Revenues

Our revenues are derived from the sale of our oil and natural gas production, as well as the sale of NGLs. Our oil, natural gas and NGL revenues do not include the effects of derivatives, which are reported in Derivative (gain) loss, net in our Condensed Consolidated Statements of Operations. The following table presents our sources of revenue as a percentage of total revenue:


	Three Months Ended June 30,
	2023		2022
Oil	71.3	%	58.1	%
NGLs	8.2	%	6.1	%
Natural gas	18.6	%	33.8	%
Other	1.9	%	2.0	%

The information below provides a discussion of, and an analysis of significant variances in, our oil, natural gas and NGL revenues, production volumes and realized sales prices (which exclude the effect of hedging unless otherwise stated) for the three months ended June 30, 2023 and 2022:


	Three Months Ended June 30,
	2023		2022			Change

	(In thousands, except realized sales price data)
Revenues:
Oil	$	89,982	$	159,264	$	(69,282)
NGLs		10,385		16,735		(6,350)
Natural gas		23,438		92,413		(68,975)
Other		2,376		5,396		(3,020)
Total revenues		126,181		273,808		(147,627)

Production Volumes:
Oil (MBbls)		1,254		1,476		(222)
NGLs (MBbls)		443		384		59
Natural gas (MMcf)		10,023		11,995		(1,972)
Total oil equivalent (MBoe)		3,368		3,859		(491)

Average daily equivalent sales (Boe/day)		37,011		42,407		(5,396)

Average realized sales prices:
Oil ($/Bbl)	$	71.76	$	107.90		(36.14)
NGLs ($/Bbl)		23.44		43.58		(20.14)
Natural gas ($/Mcf)		2.34		7.70		(5.36)
Oil equivalent ($/Boe)		36.76		69.55		(32.79)
Oil equivalent ($/Boe), including realized commodity derivatives⁽¹⁾		36.67		94.20		(57.53)

(1)

^{Excludes the effects of premium amortization.}


Volume measurements not previously defined:
MBbls — thousand barrels for crude oil, condensate or NGLs		Mcf — thousand cubic feet
MBoe — thousand barrels of oil equivalent		MMcf – million cubic feet

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Changes in average sales prices (which does not give effect to hedging) and sales volumes caused the following changes to our oil, NGL and natural gas revenues between the three months ended June 30, 2023 and 2022 (in thousands):


	Price		Volume		Total
Oil	$	(45,386)	$	(23,896)	$	(69,282)
NGLs		(9,152)		2,802		(6,350)
Natural gas		(53,782)		(15,193)		(68,975)
	$	(108,320)	$	(36,287)	$	(144,607)

Realized Prices on the Sale of Oil, NGLs and Natural Gas – Our average realized crude oil sales price differs from the WTI benchmark average crude price due primarily to premiums or discounts, crude oil quality adjustments, and volume weighting (collectively referred to as differentials). Crude oil quality adjustments can vary significantly by field as a result of quality and location. All of our crude oil is produced offshore in the Gulf of Mexico and is primarily characterized as Poseidon, Light Louisiana Sweet (“LLS”), and Heavy Louisiana Sweet (“HLS”). Similar to crude oil prices, the differentials for our offshore crude oil have also been volatile in the past. The average differential of WTI versus LLS and HLS for the three months ended June 30, 2023 was favorable to the Company and increased on average by approximately $0.35 and $1.30 per barrel, respectively, compared to the same period in 2022. The average differential for WTI versus Poseidon for the three months ended June 30, 2023 was unfavorable to the Company and declined on average by approximately $1.12 per barrel compared to the same period in 2022.

Two major components of our NGLs, ethane and propane, typically make up over 70% of an average NGL barrel. For the three months ended June 30, 2023 compared to the three months ended June 30, 2022, average prices for domestic ethane decreased by 64.0% and average domestic propane prices decreased by 68.6% as measured using a price index for Mount Belvieu. The average prices for normal butane decreased by 49.8% while other domestic NGL components decreased between 46.1% and 48.1% for the three months ended June 30, 2023 compared to the same period in 2022. The change in prices for NGLs is mostly a function of the change in crude oil prices combined with changes in propane supply and demand.

The actual prices we realize from the sale of natural gas differ from the quoted NYMEX Henry Hub price as a result of quality and location differentials. The sales points of our gas production are generally within close proximity to the Henry Hub which creates a minimal differential in the prices we receive for our production versus average Henry Hub prices.

Oil, NGLs, and Natural Gas Volumes – Production volumes decreased by 491 MBoe to 3,368 MBoe during the three months ended June 30, 2023 compared to the same period in 2022, primarily due to third party deepwater pipeline maintenance and production downtime at non-operated fields.

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Operating Expenses

The following table presents information regarding costs and expenses and selected average costs and expenses per Boe sold for the periods presented and corresponding changes:


	Three Months Ended June 30,
	2023		2022			Change

		(In thousands, except per Boe data)
Operating expenses:
Lease operating expenses	$	66,021	$	52,976	$	13,045
Gathering, transportation and production taxes		6,802		9,181		(2,379)
Depreciation, depletion, amortization and accretion		35,894		34,360		1,534
General and administrative expenses		17,393		14,967		2,426
Total operating expenses	$	126,110	$	111,484	$	14,626

Average per Boe ($/Boe):
Lease operating expenses	$	19.60	$	13.73	$	5.87
Gathering, transportation and production taxes		2.02		2.38		(0.36)
DD&A		10.66		8.90		1.76
G&A expenses		5.16		3.88		1.28
Operating expenses	$	37.44	$	28.89	$	8.55

Lease operating expenses – Lease operating expenses, which include base lease operating expenses, workovers, and facilities maintenance expense, increased $13.0 million to $66.0 million for the three months ended June 30, 2023 compared to $53.0 million for the three months ended June 30, 2022. On a component basis, base lease operating expenses increased $4.7 million, workover expenses increased $6.3 million, and facilities maintenance expense increased $2.0 million.

Base lease operating expenses increased primarily due to increased contract labor, equipment rental, and transportation costs at various fields, and increased insurance expense. The increases in workover expenses and facilities maintenance expenses were due to an increase in projects undertaken. Workovers and facilities maintenance expenses consist of costs associated with major remedial operations on completed wells to restore, maintain or improve production. Since these remedial operations are not regularly scheduled, workover and maintenance expense are not necessarily comparable from period to period.

Gathering, transportation and production taxes – Gathering, transportation and production taxes decreased $2.4 million for the three months ended June 30, 2023 compared to the three months ended June 30, 2022 due to decreases in production volumes and decreases in realized prices.

Depreciation, depletion, amortization and accretion (“DD&A”) – DD&A, which includes accretion for ARO, increased $1.5 million for the three months ended June 30, 2023 as compared to the three months ended June 30, 2022. The DD&A rate increased to $10.66 per Boe for the three months ended June 30, 2023 from $8.90 per Boe for the three months ended June 30, 2022. The increased expense was primarily due to increases in the depreciable base due to increased capital spending and increased future development costs since the second quarter of 2022, partially offset by lower production volumes.

General and administrative expenses (“G&A”) – G&A increased $2.4 million, to $17.4 million for the three months ended June 30, 2023 as compared to $15.0 million for the three months ended June 30, 2022. The increase is primarily due to increased payroll costs, incentive compensation expense and legal expenses. We incurred increased incentive compensation costs related to share-based compensation awards granted during the second quarter of 2023.

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Other Income and Expense

The following table presents the components of other income and expense for the periods presented and corresponding changes:


	Three Months Ended June 30,
	2023		2022			Change

	(In thousands)
Other income and expenses:
Derivative (gain) loss, net	$	(829)	$	(8,854)	$	8,025
Interest expense, net		10,323		18,183		(7,860)
Other (income) expense, net		(311)		(1,534)		1,223
Income tax expense		2,997		31,093		(28,096)

Derivative (gain) loss, net – During the three months ended June 30, 2023, the $0.8 million derivative gain recorded for crude oil and natural gas derivative contracts consists of $1.1 million of unrealized gain from the increase in the fair value of open contracts, partially offset by $0.3 million of realized losses. During the three months ended June 30, 2022, the $8.9 million derivative gain recorded for crude oil and natural gas derivative contracts consisted of $79.7 million in realized gains and $70.8 million of unrealized losses from the decrease in the fair value of open oil and natural gas contracts.

In the second quarter of 2022, the Company monetized a portion of existing hedge positions through restructuring of certain outstanding purchased calls covering the second half of 2022 through the first quarter of 2025 by increasing the weighted-average strike prices. These transactions resulted in net cash proceeds of $105.3 million.

Unrealized gains or losses on open derivative contracts relate to production for future periods; however, changes in the fair value of our open derivative contracts are recorded as a gain or loss on our Condensed Consolidated Statements of Operations at the end of each month. As a result of the derivative contracts we have on our anticipated production volumes through April 2028, we expect these activities to continue to impact net income (loss) based on fluctuations in market prices for natural gas. See Financial Statements – Note 4 – Derivative Financial Instruments under Part I, Item 1 of this Quarterly Report for additional information.

Interest expense, net – Interest expense, net, was $10.3 million and $18.2 million for the three months ended June 30, 2023 and 2022, respectively. The decrease of $7.9 million in 2023 is due to the redemption of the 9.75% Senior Second Lien Notes which occurred in February 2023, lower interest expense on the lower outstanding principal balance of the Term Loan and increased interest income. These decreases were partially offset by interest expense incurred on the 11.75% Senior Second Lien Notes issued in late January 2023.

Income tax expense (benefit) – Income tax expense for the three months ended June 30, 2023 and June 30, 2022 was $3.0 million and $31.1 million, respectively. For the three months ended June 30, 2023, the Company’s effective tax rate differed from the statutory Federal tax rate primarily by the impact of state income taxes, nondeductible compensation, and adjustments to the valuation allowance. For the three months ended June 30, 2022, the Company’s effective tax rate differed from the statutory Federal tax rate primarily by the impact of state income taxes and adjustments to the valuation allowance. Primarily as a result of changes in our valuation allowance on our deferred tax assets, our effective tax rate for the three months ended June 30, 2023 is not meaningful. The company’s effective tax rate was 20.1% for the three months ended June 30 2022.

As of June 30, 2023, the valuation allowance on our deferred tax assets was $19.8 million. We continually evaluate the need to maintain a valuation allowance on our deferred tax assets. Any future reduction of a portion or all of the valuation allowance would result in a non-cash income tax benefit in the period the decision occurs. See Financial Statements – Note 9 – Income Taxes under Part I, Item 1 of this Quarterly Report for additional information.

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Six Months Ended June 30, 2023 Compared to the Six Months Ended June 30, 2022

Revenues


	Six Months Ended June 30,
	2023		2022
Oil	72.6	%	60.7	%
NGLs	7.0	%	6.6	%
Natural gas	18.7	%	30.9	%
Other	1.7	%	1.8	%

The information below provides a discussion of, and an analysis of significant variance in, our oil, natural gas and NGL revenues, production volumes and realized sales prices (which exclude the effect of hedging unless otherwise stated) for the six months ended June 30, 2023 and 2022:


	Six Months Ended June 30,
	2023		2022			Change

		(In thousands, except realized sales price data)
Revenues:
Oil	$	186,982	$	281,966	$	(94,984)
NGLs		18,180		30,555		(12,375)
Natural gas		48,242		143,779		(95,537)
Other		4,502		8,512		(4,010)
Total revenues	$	257,906	$	464,812	$	(206,906)

Production Volumes:
Oil (MBbls)		2,604		2,780		(176)
NGLs (MBbls)		738		733		5
Natural gas (MMcf)		17,699		22,466		(4,767)
Total oil equivalent (MBoe)		6,292		7,257		(965)

Average daily equivalent sales (Boe/day)		34,762		40,094		(5,332)

Average realized sales prices:
Oil ($/Bbl)	$	71.81	$	101.43	$	(29.62)
NGLs ($/Bbl)		24.63		41.68		(17.05)
Natural gas ($/Mcf)		2.73		6.40		(3.67)
Oil equivalent ($/Boe)		40.27		62.88		(22.61)
Oil equivalent ($/Boe), including realized commodity derivatives⁽¹⁾		40.19		70.53		(30.34)

(1)

^{Excludes the effects of premium amortization and write-offs.}

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Changes in average sales prices (which does not give effect to hedging) and sales volumes caused the following changes to our oil, NGL and natural gas revenues between the six months ended June 30, 2023 and 2022 (in thousands):


	Price		Volume		Total
Oil	$	(77,129)	$	(17,855)	$	(94,984)
NGLs		(12,751)	$	376		(12,375)
Natural gas		(65,032)		(30,505)		(95,537)
	$	(154,912)	$	(47,984)	$	(202,896)

Realized Prices on the Sale of Oil, NGLs and Natural Gas – Our average realized crude oil sales price differs from the WTI benchmark average crude price due primarily to premiums or discounts, crude oil quality adjustments, and volume weighting (collectively referred to as differentials). Crude oil quality adjustments can vary significantly by field as a result of quality and location. All of our crude oil is produced offshore in the Gulf of Mexico and is primarily characterized as Poseidon, LLS, and HLS. Similar to crude oil prices, the differentials for our offshore crude oil have also experienced volatility in the past. The average differential of WTI versus LLS for the six months ended June 30, 2023 was favorable to the Company and increased on average by approximately $0.31 per barrel, compared to the same period in 2022. The average differential of WTI versus HLS for the six months ended June 30, 2023 was favorable to the Company and remained flat compared to the same period in 2022. The average differential for WTI versus Poseidon for the six months ended June 30, 2023 was unfavorable to the Company and declined on average by approximately $0.86 per barrel compared to the same period in 2022.

Two major components of our NGLs, ethane and propane, typically make up over 70% of an average NGL barrel. For the six months ended June 30, 2023 compared to the six months ended June 30, 2022, average prices for domestic ethane decreased by 53.3% and average domestic propane prices decreased by 58.4% as measured using a price index for Mount Belvieu. The average prices for normal butane decreased by 39.0% while other domestic NGLs components decreased between 38.9% and 41.3% for the six months ended June 30, 2023 compared to the same period in 2022. The change in prices for NGLs is mostly a function of the change in crude oil prices combined with changes in propane supply and demand.

Oil, NGLs, and Natural Gas Volumes – Production volumes decreased by 965 MBoe to 6,292 MBoe during the six months ended June 30, 2023 compared to the same period in 2022 primarily due to shut-ins related to field and well maintenance at Mobile Bay during the first quarter of 2023 as well as third party deepwater pipeline maintenance and production downtime at non-operated fields during the first and second quarters of 2023.

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Operating Expenses

The following table presents information regarding costs and expenses and selected average costs and expenses per Boe sold for the periods presented and corresponding changes:


	Six Months Ended June 30,
	2023		2022			Change

	(In thousands, except per Boe data)
Operating expenses:
Lease operating expenses	$	131,207	$	96,387	$	34,820
Gathering, transportation and production taxes		12,938		14,448		(1,510)
Depreciation, depletion, amortization and accretion		66,028		65,271		757
General and administrative expenses		37,312		28,743		8,569
Total operating expenses	$	247,485	$	204,849	$	42,636

Average per Boe ($/Boe):
Lease operating expenses	$	20.85	$	13.28	$	7.57
Gathering, transportation and production taxes		2.06		1.99		0.07
DD&A		10.49		8.99		1.50
G&A expenses		5.93		3.96		1.97
Operating expenses	$	39.33	$	28.22	$	11.11

Lease operating expenses – Lease operating expenses, which include base lease operating expenses, workovers, and facilities maintenance expense, increased $34.8 million to $131.2 million for the six months ended June 30, 2023 compared to $96.4 million for the six months ended June 30, 2022. On a component basis, base lease operating expenses increased $16.0 million, workover expenses increased $8.4 million, facilities maintenance expense increased $10.7 million, and hurricane repairs decreased $0.3 million.

Base lease operating expenses increased due to increased expenses related to a full six months of expenses at the fields acquired during February 2022 as well as increased contract labor, equipment rental, and transportation costs at various fields, and increased insurance expense. The increases in workover expenses and facilities maintenance expenses were due to an increase in projects undertaken. Workovers and facilities maintenance expenses consist of costs associated with major remedial operations on completed wells to restore, maintain or improve production. Since these remedial operations are not regularly scheduled, workover and maintenance expense are not necessarily comparable from period to period.

Gathering, transportation and production taxes – Gathering, transportation and production taxes decreased $1.5 million for the six months ended June 30, 2023 compared to the six months ended June 30, 2022 primarily due to decreases in production volumes and decreases in realized prices partially offset by the transportation contract related to the properties acquired in February 2022.

Depreciation, depletion, amortization and accretion – DD&A, which includes accretion for ARO, increased $0.8 million for the six months ended June 30, 2023 as compared to the six months ended June 30, 2022. The DD&A rate increased to $10.49 per Boe for the six months ended June 30, 2023 from $8.99 per Boe for the six months ended June 30, 2022. The slight increase in DD&A expense was primarily due to increases in the depreciable base due to increased capital spending and increased future development costs since the second quarter of 2022, partially offset by lower production volumes.

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General and administrative expenses – G&A increased $8.6 million to $37.3 million for the six months ended June 30, 2023 as compared to $28.7 million for the six months ended June 30, 2022. The increase is primarily due to increased payroll costs, incentive compensation expense, and legal expenses. The increase was partially offset by a $2.2 million employee retention credit recorded during the six months ended June 30, 2023. We incurred increased incentive compensation costs related to the higher value of the short-term cash-based incentive compensation awards granted in 2022 as compared to the value of awards granted in 2021, the higher grant date fair value of RSU and PSU awards granted during 2022 as compared to the value of awards granted in 2021, as well as share-based compensation awards granted during the second quarter of 2023.

Other Income and Expense

The following table presents the components of other income and expense for the periods presented and corresponding changes:


	Six Months Ended June 30,
	2023		2022			Change

	(In thousands)
Other income and expenses:
Derivative (gain) loss, net	$	(40,069)	$	71,143	$	(111,212)
Interest expense, net		25,036		38,066		(13,030)
Other (income) expense, net		(78)		(629)		551
Income tax expense		11,636		30,404		(18,768)

Derivative(gain) loss, net – During the six months ended June 30, 2023, the $40.1 million derivative gain recorded for crude oil and natural gas derivative contracts consists of $0.5 million of realized losses on settled contracts and $40.6 million of unrealized gains from the increase in the fair value of open contracts. During the six months ended June 30, 2022, the $71.1 million derivative loss recorded for crude oil and natural gas derivative contracts consisted of $36.0 million in realized gains on settled contracts and $107.1 million of unrealized losses from the decrease in the fair value of open oil and natural gas contracts.

Unrealized gains or losses on open derivative contracts relate to production for future periods; however, changes in the fair value of all of our open derivative contracts are recorded as a gain or loss on our Condensed Consolidated Statements of Operations at the end of each month. As a result of the derivative contracts we have on our anticipated production volumes through April 2028, we expect these activities to continue to impact net income (loss) based on fluctuations in market prices for natural gas. See Financial Statements – Note 4 – Derivative Financial Instruments under Part I, Item 1 of this Quarterly Report for additional information.

Interest expense, net – Interest expense, net was $25.0 million and $38.1 million for the six months ended June 30, 2023 and 2022, respectively. The decrease of $13.0 million in 2023 is due to the redemption of the 9.75% Senior Second Lien Notes which occurred in February 2023, lower interest expense on the lower outstanding principal balance of the Term Loan, and increased interest income. These decreases were partially offset by interest expense incurred on the 11.75% Senior Second Lien Notes issued in late January 2023.

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Income tax expense (benefit) – Income tax expense for the six months ended June 30, 2023 and June 30, 2022 was $11.6 million and $30.4 million, respectively. For the six months ended June 30, 2023, the Company’s effective tax rate differed from the statutory Federal tax rate primarily by the impact of state income taxes, nondeductible compensation, and adjustments to the valuation allowance. For the six months ended June 30, 2022, the Company’s effective tax rate differed from the statutory Federal tax rate primarily by the impact of state income taxes and adjustments to the valuation allowance. The Company’s effective tax rate was 45.6% and 20.1% for the six months ended June 30, 2023 and 2022, respectively.

As of June 30, 2023, the valuation allowance on our deferred tax assets was $19.8 million. We continually evaluate the need to maintain a valuation allowance on our deferred tax assets. Any future reduction of a portion or all of the valuation allowance would result in a non-cash income tax benefit in the period the decision occurs. See Financial Statements – Note 9 –Income Taxes under Part I, Item 1 of this Quarterly Report for additional information.

Liquidity and Capital Resources

Liquidity Overview

Our primary liquidity needs are to fund capital and operating expenditures and strategic acquisitions to allow us to replace our oil and natural gas reserves, repay and service outstanding borrowings, operate our properties and satisfy our ARO obligations. We have funded such activities in the past with cash on hand, net cash provided by operating activities, sales of property, securities offerings and bank and other borrowings, and expect to continue to do so in the future.

The primary sources of our liquidity are cash from operating activities and borrowings under our Credit Agreement. As of June 30, 2023, we had $171.6 million cash on hand, and $50.0 million available under our Credit Agreement, based on a borrowing base of $50.0 million. We also have up to approximately $83.0 million of availability through our “at-the-market” equity offering program, pursuant to which we may offer and sell shares or our common stock from time to time. We believe our access to the equity markets from our “at-the-market” equity offering program, our reserve based lending currently available under our Credit Agreement, along with our cash position, will provide us with additional liquidity to continue our growth to take advantage of the current commodity environment.

Sources and Uses of Cash


	Six Months Ended June 30,
	2023		2022			Change

	(In thousands)
Operating activities	$	49,632	$	237,759	$	(188,127)
Investing activities		(34,538)		(78,900)		44,362
Financing activities		(304,824)		(26,934)		(277,890)

Operating activities – Net cash provided by operating activities decreased $188.1 million for the six months ended June 30, 2023 compared to the corresponding period in 2022. This was primarily due to (i) the $206.9 million decrease in revenues, (ii) the $42.6 million increase in operating expenses, and (iii) derivative cash settlements payments of $4.4 million during the six months ended June 30, 2023 as compared to net derivative cash settlement receipts of $70.2 million during the six months ended June 30, 2022. The decrease in revenues was due to a decrease in realized prices for oil, NGLs and natural gas, and to a lesser extent the decrease in production volumes. During the six months ended June 30, 2022 derivative cash settlement receipts were due to the $105.3 million of net cash proceeds received related to the monetization of certain natural gas call contracts.

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These decreases in operating cash flow were partially offset by (i) the changes in operating assets and liabilities (excluding ARO settlements) which increased operating cash flows by $6.1 million as compared to a decrease of $37.9 million for the six months ended June 30, 2022, primarily related to lower oil and natural gas receivables balances due to decreased realized prices and lower accounts payable and accrued liabilities in the current period and (ii) decreased ARO settlements of $11.8 million during the six months ended June 30, 2023 as compared to $39.8 million during the six months ended June 30, 2022.

Investing activities – Net cash used in investing activities decreased $44.4 million for the six months ended June 30, 2023 compared to the corresponding period in 2022. The decrease was primarily due to the acquisition of properties for $47.6 million during the six months ended June 30, 2022.

Financing activities – During the six months ended June 30, 2023, cash used in financing activities increased by $277.9 million for the six months ended June 30, 2023 compared to the corresponding period in 2022. This was due to the redemption of the $552.5 million principal amount outstanding 9.75% Senior Second Lien Notes on February 8, 2023, which was partially offset by the net cash proceeds of $270.8 million received from the issuance of the 11.75% Senior Second Lien Notes. Additionally, the principal repayments on the Term Loan decreased by $5.8 million.

Derivative Financial Instruments – From time to time, we use various derivative instruments to manage a portion of our exposure to commodity price risk from sales of oil and natural gas. See Financial Statements – Note 4 – Derivative Financial Instruments under Part I, Item 1 of this Quarterly Report for additional information about our derivative activities. The following table summarizes the historical results of our hedging activities:


	Three Months Ended June 30,				Six Months Ended June 30,
	2023		2022		2023		2022
Crude Oil ($/Bbl):
Average realized sales price, before the effects of derivative settlements	$	71.76	$	107.90	$	71.81	$	101.43
Effects of realized commodity derivatives		—		(18.22)		—		(17.47)
Average realized sales price, including realized commodity derivatives	$	71.76	$	89.68	$	71.81	$	83.96
Natural Gas ($/Mcf)
Average realized sales price, before the effects of derivative settlements	$	2.34	$	7.70	$	2.73	$	6.40
Effects of realized commodity derivatives⁽¹⁾		(0.03)		10.17		(0.03)		4.63
Average realized sales price, including realized commodity derivatives	$	2.31	$	17.87	$	2.70	$	11.03

(1)

^{Excludes the effects of premium amortization.}

Income Taxes – For 2023, the Company does not expect to owe any cash taxes. The Company made income tax payments of $2.2 million for federal and $0.3 million for state purposes, and has income taxes receivable of $1.7 million for federal and $0.2 million for state for the six months ended June 30, 2023. See Financial Statements – Note 9 –Income Taxes under Part I, Item 1 of this Quarterly Report for additional information.

Employee Retention Credit – Under the Consolidated Appropriations Act of 2021, the Company recognized a $2.2 million Employee Retention Credit during the six months ended June 30, 2023, which is included as a credit to General and administrative expenses in the Condensed Consolidated Statement of Operations.

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Capital Expenditures

The level of our investment in oil and natural gas properties changes from time to time depending on numerous factors, including the prices of crude oil, NGLs and natural gas, acquisition opportunities, available liquidity and the results of our exploration and development activities. The following table presents our capital expenditures for exploration, development and other leasehold costs:


	Six Months Ended June 30,
	2023		2022

	(In thousands)
Exploration⁽¹⁾	$	2,660	$	9,854
Development⁽¹⁾		18,360		9,186
Acquisitions of interests		—		47,625
Seismic and other		1,979		6,449
Investments in oil and gas property/equipment – accrual basis	$	22,999	$	73,114

(1)

^{Reported geographically in the subsequent table.}

The following table presents our exploration and development capital expenditures geographically in the Gulf of Mexico:


	Six Months Ended June 30,
	2023		2022

	(In thousands)

Conventional shelf ⁽¹⁾	$	6,898	$	7,849
Deepwater		14,122		11,191
Exploration and development capital expenditures – accrual basis	$	21,020	$	19,040

(1)

^{Includes exploration and development capital expenditures in Alabama state waters.}

The capital expenditures are included within Oil and natural gas properties and other, net on the Condensed Consolidated Balance Sheets and recorded on an accrual basis. The capital expenditures reported within the Investing activities section of the Condensed Consolidated Statements of Cash Flows include adjustments to report cash payments related to capital expenditures. Our capital expenditures for the six months ended June 30, 2023 were financed by cash flow from operations and cash on hand.

Acquisitions – There were no acquisitions during the six months ended June 30, 2023. During the six months ended June 30, 2022, the Company acquired the working interest and operatorship of certain oil and natural gas producing properties in federal shallow waters in the Gulf of Mexico at Ship Shoal 230, South Marsh Island 27/Vermilion 191, and South Marsh Island 73 fields on February 1, 2022 and April 1, 2022. After normal and customary post-effective date adjustments (including net operating cash flow attributable to the properties from the effective date to the respective close date), cash consideration of approximately $34.0 and $17.5 million was paid to the sellers. The transaction was funded using cash on hand.

Asset Retirement Obligations – Each quarter, we review and revise our ARO estimates. Our ARO estimates as of June 30, 2023 and December 31, 2022 were $480.8 million and $466.4 million, respectively. The increase is primarily due to ARO accretion and upward revisions of estimates, partially offset by liabilities settled. As our ARO estimates are for work to be performed in the future, and in the case of our non-current ARO, extend from one to many years in the future, actual expenditures could be substantially different than our estimates. See Risk Factors, under Part I, Item 1A of our 2022 Annual Report for additional information.

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TVPX Transaction – On May 15, 2023, we acquired a corporate aircraft from a company affiliated with and controlled by our CEO. The purchase price of the aircraft was $19.1 million, which was paid using $9.0 million of cash on hand and through the assumption of the TVPX Loan, which had a fair market value of $10.1 million on the date of assumption. A valuation prepared by an independent third-party appraiser was one of the components used in determining the purchase price value. Factors considered for purchasing the aircraft were the primary use of making business travel efficient as well as our intent to charter out the aircraft to defray a portion of the operating costs and certain tax considerations and benefits. The terms of this transaction were reviewed and approved by the Audit Committee of the Company’s Board of Directors. See Note 2 – Debt and Note 12 – Related Party Transactions for additional information.

Drilling Activity

We did not drill any wells during the six months ended June 30, 2023. During the six months ended June 30, 2022, we completed the East Cameron 349 B-1 well (Cota). The Cota well is in the Monza Joint Venture Drilling Program. See Financial Statements – Note 6 –Joint Venture Drilling Program under Part I, Item 1 of this Quarterly Report for additional information.

Debt

TVPX Loan – On May 15, 2023, we acquired a corporate aircraft. In connection with the acquisition, the TVPX Loan was assumed by TVPX Aircraft Solutions Inc., not in its individual capacity but as owner trustee of the trust which holds title to the aircraft, a wholly owned indirect subsidiary of the Company, as the borrower. At the time of the assumption, the TVPX Loan had an aggregate principal amount of $11.8 million outstanding. The TVPX Loan bears a fixed interest rate of 2.49% per annum for a term of 41 months and requires monthly amortization payments of $91.7 thousand plus accrued interest, which began on May 17, 2023, and a balloon payment of $8.0 million at the end of the loan term. The TVPX Loan is guaranteed by the Company on an unsecured basis. See Financial Statements – Note 2 – Debt under Part I, Item 1 of this Quarterly Report for additional information.

Term Loan – As of June 30, 2023, we had $128.7 million of Term Loan principal outstanding. The Term Loan requires quarterly amortization payments, bears interest at a fixed rate of 7% per annum and will mature on May 19, 2028. The Term Loan is non-recourse to the Company and its subsidiaries other than Subsidiary Borrowers and the subsidiary that owns the equity of the Subsidiary Borrowers, and is not secured by any assets other than first lien security interests in the equity in the Subsidiary Borrowers and a first lien mortgage security interest and mortgages on certain assets of Subsidiary Borrowers (the Mobile Bay Properties). See Financial Statements – Note 2 – Debt under Part I, Item 1 of this Quarterly Report for additional information.

Credit Agreement – During the six months ended June 30, 2023, we had no borrowings incurred or outstanding under the Credit Agreement.

11.75% Senior Second Lien Notes due 2026 – On January 27, 2023, we issued and sold $275 million in aggregate principal amount of our 11.75% Senior Second Lien Notes at par with an interest rate of 11.75% per annum that matures on February 1, 2026. The Senior Second Lien Notes are secured by a second-priority lien on all of our assets that are secured under the Credit Agreement. As of June 30, 2023, we had outstanding $275.0 million principal of 11.75% Senior Second Lien Notes. See Financial Statements – Note 2 – Debt under Part I, Item 1 of this Quarterly Report for additional information.

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9.75% Senior Second Lien Notes due 2023 – On February 8, 2023, we redeemed all of the 9.75% Senior Second Lien Notes outstanding at a redemption price of 100.000%, plus accrued and unpaid interest to the redemption date. The Company used the net proceeds of $270.8 million from the issuance of the 11.75% Senior Second Lien Notes due 2026 and cash on hand of $296.1 million to fund the redemption. See Financial Statements – Note 2 – Debt under Part I, Item 1 of this Quarterly Report for additional information.

Debt Covenants – The Credit Agreement contains financial covenants calculated as of the last day of each fiscal quarter, which includes thresholds on financial ratios, as defined in the respective Credit Agreement. We were in compliance with all applicable covenants of Credit Agreement as of and for the period ended June 30, 2023. See Financial Statements – Note 2 – Debt under Part I, Item 1 of this Quarterly Report for additional information.

The Subsidiary Borrowers

On May 19, 2021, we formed A-I LLC and A-II LLC, both indirect, wholly-owned subsidiaries of W&T Offshore, Inc., through their parent, Aquasition Energy LLC (collectively, the “Aquasition Entities”). Concurrently, A-I LLC and A-II LLC, entered into a credit agreement providing for the Term Loan. See Financial Statements – Note 5 – Subsidiary Borrowers under Part I, Item 1 in this Quarterly Report for additional information.

We designated the Aquasition Entities as unrestricted subsidiaries under the Indenture (the “Unrestricted Subsidiaries”). Having been so designated, the Unrestricted Subsidiaries do not guarantee the 11.75% Senior Second Lien Notes and the liens on the assets sold to the Unrestricted Subsidiaries have been released under the Credit Agreement. The Unrestricted Subsidiaries are not bound by the covenants contained in the Credit Agreement or the Indenture. Under the Subsidiary Credit Agreement and related instruments, assets of the Aquasition Entities may not be available to mortgage or pledge as security to secure new indebtedness of the Company and its other subsidiaries. See Financial Statements – Note 2 – Debt under Part I, Item 1 in this Quarterly Report for additional information.

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Below is consolidating balance sheet information reflecting the elimination of the accounts of our Unrestricted Subsidiaries from our Condensed Consolidated Balance Sheet as of June 30, 2023 (in thousands):


	Consolidated Balance Sheet		Eliminations of Unrestricted Subsidiaries		Consolidated Balance Sheet of restricted subsidiaries
Assets
Current assets:
Cash and cash equivalents	$	171,627	$	(5,899)	$	165,728
Restricted cash		4,417		—		4,417
Receivables:
Oil and natural gas sales		41,342		(18,411)		22,931
Joint interest, net		13,875		27,400		41,275
Income taxes		1,941		—		1,941
Total receivables		57,158		8,989		66,147
Prepaid expenses and other assets		21,365		(125)		21,240
Total current assets		254,567		2,965		257,532

Oil and natural gas properties and other, net		737,740		(289,959)		447,781

Restricted deposits for asset retirement obligations		22,092		—		22,092
Deferred income taxes		45,700		—		45,700
Other assets		42,118		(11,486)		30,632
Total assets	$	1,102,217	$	(298,480)	$	803,737
Liabilities and Shareholders’ Equity (Deficit)
Current liabilities:
Accounts payable	$	70,403	$	(8,996)	$	61,407
Undistributed oil and natural gas proceeds		31,178		(3,625)		27,553
Asset retirement obligations		37,763		—		37,763
Accrued liabilities		39,323		(19,036)		20,287
Current portion of long-term debt		30,550		(30,074)		476
Income tax payable		10		—		10
Total current liabilities		209,227		(61,731)		147,496
Long-term debt
Principal		382,697		(97,222)		285,475
Unamortized debt issuance costs		(9,676)		2,304		(7,372)
Long-term debt, net		373,021		(94,918)		278,103

Asset retirement obligations, less current portion		443,069		(66,136)		376,933
Other liabilities		52,037		(22,020)		30,017
Deferred income taxes		72		—		72
Common stock		1		—		1
Shareholders' equity (deficit):
Additional paid-in capital		579,849		—		579,849
Retained deficit		(530,892)		(53,675)		(584,567)
Treasury stock, at cost		(24,167)		—		(24,167)
Total shareholders’ equity (deficit)		24,791		(53,675)		(28,884)
Total liabilities and shareholders’ equity (deficit)	$	1,102,217	$	(298,480)	$	803,737

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Below is Consolidating Statement of Operations information reflecting the elimination of the accounts of our Unrestricted Subsidiaries from our Condensed Consolidated Statement of Operations for the six months ended June 30, 2023 (in thousands):


		Consolidated Statement of Operations		Eliminations of Unrestricted Subsidiaries		Consolidated Statement of Operations of restricted subsidiaries
Revenues:
Oil	$	186,982	$	(288)	$	186,694
NGLs		18,180		(11,660)		6,520
Natural gas		48,242		(32,354)		15,888
Other		4,502		(2,258)		2,244
Total revenues		257,906		(46,560)		211,346
Operating expenses:
Lease operating expenses		131,207		(48,157)		83,050
Gathering, transportation and production taxes		12,938		(4,054)		8,884
Depreciation, depletion, amortization and accretion		66,028		2,375		68,403
General and administrative expenses		37,312		(654)		36,658
Total operating expenses		247,485		(50,490)		196,995
Operating income		10,421		3,930		14,351

Interest expense, net		25,036		(5,411)		19,625
Derivative (gain) loss, net		(40,069)		52,389		12,320
Other income, net		(78)		—		(78)
Income (loss) before income taxes		25,532		(43,048)		(17,516)
Income tax expense		11,636		—		11,636
Net (loss) income	$	13,896	$	(43,048)	$	(29,152)

The following table presents our produced oil, NGLs and natural gas volumes (net to our interests) from the Subsidiary Borrowers for the periods indicated:


	Six Months Ended June 30,
Production Volumes:	2023	2022
Oil (MBbls)	7	7
NGLs (MBbls)	465	468
Natural gas (MMcf)	11,570	15,166
Total oil equivalent (MBoe)	2,400	3,003

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Contractual Obligations

As of June 30, 2023, there were no long-term drilling rig commitments. Except as disclosed herein, contractual obligations as of June 30, 2023 did not change materially from the disclosures in Management’s Discussion and Analysis of Financial Condition and Results of Operations, under Part II, Item 7 of our 2022 Annual Report.

Critical Accounting Policies and Estimates

We consider accounting policies related to revenue recognition, full cost accounting, impairment of oil and natural gas properties, oil and natural gas reserve quantities, asset retirement obligations, and income taxes as critical accounting policies. These policies include significant estimates made by management using information available at the time the estimates are made. However, these estimates could change materially if different information or assumptions were used.

There have been no changes to our critical accounting policies which are summarized in Management’s Discussion and Analysis of Financial Condition and Results of Operations under Part II, Item 7 of our 2022 Annual Report.

Recent Accounting Pronouncements

There were no recently issued accounting standards material to us.

Item 3. Quantitative and Qualitative Disclosures About Market Risk

Information about the types of market risks for the six months ended June 30, 2023 did not change materially from the disclosures in Quantitative and Qualitative Disclosures About Market Risk under Part II, Item 7A of our 2022 Annual Report. In addition, the information contained herein should be read in conjunction with the related disclosures in our 2022 Annual Report.

Item 4. Controls and Procedures

We have established disclosure controls and procedures designed to ensure that material information required to be disclosed in our reports filed under the Exchange Act is recorded, processed, summarized and reported within the time periods specified by the SEC and that any material information relating to us is accumulated and communicated to our management, including our CEO and Chief Financial Officer (“CFO”), as appropriate to allow timely decisions regarding required disclosures. In designing and evaluating our disclosure controls and procedures, our management recognizes that controls and procedures, no matter how well designed and operated, can provide only reasonable assurance of achieving desired control objectives. In reaching a reasonable level of assurance, our management necessarily was required to apply its judgment in evaluating the cost-benefit relationship of possible controls and procedures.

As required by Exchange Act Rule 13a-15(b), our CEO and CFO performed an evaluation of the effectiveness of the design and operation of our disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) as of the end of the period covered by this Quarterly Report. Based on that evaluation, our CEO and CFO have each concluded that as of June 30, 2023, our disclosure controls and procedures are effective to ensure that information we are required to disclose in reports filed or submitted under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms, and that our controls and procedures are designed to ensure that information required to be disclosed by us in such reports is accumulated and communicated to our management, including our CEO and CFO, as appropriate to allow timely decisions regarding required disclosure.

During the quarter ended June 30, 2023, there was no change in our internal control over financial reporting that materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

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PART II – OTHER INFORMATION

Item 1. Legal Proceedings

See Financial Statements – Note 11 – Contingencies under Part I Item 1 of this Quarterly Report for information on various legal proceedings to which we are a party or our properties are subject.

Item 1A. Risk Factors

In addition to the information set forth in this Quarterly Report, investors should carefully consider the risk factors and other cautionary statements included under Part I, Item 1A, Risk Factors, in our 2022 Annual Report, together with all of the other information included in this Quarterly Report, and in our other public filings, which could materially affect our business, financial condition or future results. Additional risks and uncertainties not currently known to us or that we currently deem to be immaterial also may materially adversely affect our business, financial condition or future results.

Notwithstanding the matters discussed herein, there have been no material changes in our risk factors as previously disclosed in Part I, Item 1A, Risk Factors, in our 2022 Annual Report.

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds

None.

Item 3. Defaults Upon Senior Securities

None.

Item 4. Mine Safety Disclosures

None.

Item 5. Other Information

During the three months ended June 30, 2023, none of our directors or “officers” (as such term is defined in Rule 16a-1(f) under the Exchange Act) adopted or terminated a “Rule 10b5-1 trading arrangement” or “non-Rule 10b5-1 trading arrangement” (as each term is defined in Item 408(a) of Regulation S-K).

Item 6. Exhibits


Exhibit Number		Description

3.1*		Second Amended and Restated Articles of Incorporation of W&T Offshore, Inc.

3.2		Fourth Amended and Restated Bylaws of W&T Offshore, Inc. (Incorporated by reference to Exhibit 3.1 of the Company’s Current Report on Form 8-K, filed April 26, 2023 (File No. 001-32414))

4.1*		First Supplemental Indenture, dated as of May 25, 2023, among Falcon Aero Holdings LLC, Falcon Aero Holdco LLC, W&T Offshore, Inc., the other Guarantors party thereto and Wilmington Trust, National Association, as trustee.

10.1		W&T Offshore, Inc. 2023 Incentive Compensation Plan (Incorporated by reference to Exhibit 10.1 of the Company’s Current Report on Form 8-K, filed June 20, 2023 (File No. 001-32414))

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10.2*		W&T Offshore, Inc. Change in Control Severance Plan

10.3*		Form of Restricted Stock Unit Agreement (Service-based Vesting), pursuant to the W&T Offshore, Inc. Amended and Restated Incentive Compensation Plan

10.4*		Form of Restricted Stock Unit Agreement (Performance Vesting), pursuant to the W&T Offshore, Inc. Amended and Restated Incentive Compensation Plan

10.5*		Form of 2023 Executive Annual Incentive Award Agreement

10.6		Amended and Restated Employment Agreement between W&T Offshore, Inc. and Tracy W. Krohn (Incorporated by reference to Exhibit 10.1 of the Company’s Current Report on Form 8-K filed on April 26, 2023 (File No. 001-32414))

10.7†		Twelfth Amendment to the Sixth Amended and Restated Credit Agreement, dated as of May 15, 2023, by and among W&T Offshore, Inc., the guarantor subsidiaries party thereto, Alter Domus (US) LLC, and the various agents and lenders and other parties thereto (Incorporated by reference to Exhibit 10.1 of the Company’s Current Report on Form 8 K, filed May 19, 2023 (File No. 001 32414))

31.1*		Section 302 Certification of Chief Executive Officer

31.2*		Section 302 Certification of Chief Financial Officer

32.1**		Section 906 Certification of Chief Executive Officer and Chief Financial Officer

101.INS*		Inline XBRL Instance Document

101.SCH*		Inline XBRL Schema Document

101.CAL*		Inline XBRL Calculation Linkbase Document

101.DEF*		Inline XBRL Definition Linkbase Document

101.LAB*		Inline XBRL Label Linkbase Document

101.PRE*		Inline XBRL Presentation Linkbase Document

104*		Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101)

*	Filed herewith.

**	Furnished herewith.

†	Certain schedules and similar attachments to this agreement have been omitted pursuant to Item 601(a)(5) of Regulation S-K. The Company hereby undertakes to furnish a supplemental copy of each such omitted schedule or similar attachment to the SEC upon request.

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SIGNATURE

Pursuant to the requirements of Section 13 or 15(d) of the Exchange Act, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized, on August 2, 2023.


	W&T OFFSHORE, INC.

	By:	/s/ Sameer Parasnis
		Sameer Parasnis
		Executive Vice President and Chief Financial Officer (Principal Financial Officer), duly authorized to sign on behalf of the registrant